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185-019
Originated: Delivered to:12-Nov-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1D-30 50-029-22965-00 910358412 Kuparuk River Leak Detect Log Field- Final 14-Oct-25 0 12 1D-30 50-029-22965-00 910358412 Kuparuk River Multi Finger Caliper Field & Processed 15-Oct-25 0 13 1D-30 50-029-22965-00 910390851 Kuparuk River Packer Setting Record Field- Final 31-Oct-25 0 14 1E-02 50-029-20472-00 910390619 Kuparuk RiverMulti Finger CaliperField & Processed 28-Oct-25 0 15 1E-36 50-029-22927-00 910357198 Kuparuk River Tubing Cut Record Field- Final 19-Oct-25 0 16 2U-06 50-029-21282-00 910390614 Kuparuk River Multi Finger Caliper Field & Processed 19-Oct-25 0 17 3K-20 50-029-23019-00 910390195 Kuparuk River Packer Setting Record Field- Final 22-Oct-25 0 18 3R-17 50-029-22242-00 910433126 Kuparuk River Packer Setting Record Field- Final 11-Nov-25 0 1910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:200-104180-050198-213185-019201-088192-005T41088T41088T41088T41089T41090T41091T41092T41093Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.12 11:46:38 -09'00'2U-0650-029-21282-00 910390614Kuparuk RiverMulti Finger CaliperField & Processed19-Oct-2501185-019 Originated: Delivered to:5-Nov-25Alaska Oil & Gas Conservation Commiss05Nov25-NR ! "# $$%$ !&$$'($)*%+ ($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3T-730 50-103-20907-00-00 225-010 Kuparuk River WL TTiX-IPROF FINAL FIELD 6-Oct-253J-03 50-029-21399-00-00 185-164 Kuparuk River WL PPROF FINAL FIELD 7-Oct-252X-01 50-029-20963-00-00 183-084 Kuparuk River WL IPROF FINAL FIELD 10-Oct-252Z-07 50-029-20946-00-00 183-064 Kuparuk River WL CBP FINAL FIELD 11-Oct-252Z-03 50-029-20964-00-00 183-085 Kuparuk River WL IPROF FINAL FIELD 14-Oct-253R-17 50-029-22242-00-00 192-005 Kuparuk River WL LDL FINAL FIELD 16-Oct-253S-722 50-103-20886-00-00 224-066 Kuparuk River WL TTiX-IPROF FINAL FIELD 20-Oct-252U-06 50-029-21282-00-00 185-019 Kuparuk River WL RBP FINAL FIELD 25-Oct-253T-731 50-103-20905-00-00 224-156 Kuparuk River WL Cutter FINAL FIELD 2-Nov-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8 " ! - +" 8 # !(3 . 8 ) "3 8 # !9 3 : 8" +8 6 8 8 " 8 # !;" " 3 - 3 " 3 ""+ 3 + < +3!% T41052T41053T41054T41055T41056T41057T41058T41059T410602U-0650-029-21282-00-00185-019Kuparuk RiverWLRBPFINAL FIELD25-Oct-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.05 12:45:23 -09'00' XHVZE ?roject Well History File' [e This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier RESCAN DIGITAL DATA [3 Color items: [3 Diskettes, No, B Grayscale items: [3 Other, No/Type c] Poor Qual!ty Orig~npls: [3 Other: '~ NOTES: -~ OVERSIZED (Scannable) [] Maps: E] Other items scannable by large scanner BY: BEVERLY BREN V~ SHERYL MARIA LOWELl. Project Proofing BY: ~ BREN VINCENT SHERYL MARIA LOWELl. OVERSIZED (Non-Scannable) Logs of various kinds Other DATE: 7/~/~Sl Scanning Preparation "~ x30= (.OO + BY: B~RLY ~)VINCENT SHERYL MARIA LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FI!/E: ' ~/ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ NO BY; BEVERLY BREN VINCEN~ARIA LOWELL DATE:/~'/¢~..Js/ o,..,.,,aue 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO (SCANNING 18 COMPLETE AT THIS POINT UNLE,~ SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ; ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~si General'Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd STATE OF ALASKA KA OIL AND GAS CONSERVATION COMMON ` RE RT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Ferforations r Perforate r Other p" Install Patch Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r " Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 185 -019 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service -- 50- 029 - 21282 -00 "QQ 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25644 — 2U -06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8286 feet Plugs (measured) None true vertical 6152 feet Junk (measured) 7901', 8044' Effective Depth measured 8132 feet Packer (measured) 6788, 6817, 7406, 7799 true vertical 6048 feet (true vertical) 5144, 5163, 5550, 5823 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 105 105 SURFACE 3605 9.625 3642 2979 PRODUCTION 8181 7 8214 6103 SCANNED JAN 2 $ 2013 KZ C .. i „ - �. a '1 `).1 1, OCT w.., , e 3 L G 1,_ Perforation depth: Measured depth: 7700 -7754, 7851 -7914, 7980 -8007' True Vertical Depth: 5754 -5792, 5859 -5902, 5947 -5966 A ' 1 L' Tubing (size, grade, MD, and TVD) 3.5, L -80, 7654 MD, 5721 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 6788 MD and 5144 TVD PACKER - WEATHERFORD ER PACKER © 6817 MD and 5163 TVD ✓ PACKER - PATCH PACKER @ 7329' MD and 5497 TVD PACKER - PATCH PACKER @ 7350' MD and 5511 TVD PACKER - BAKER FHL RETRIEVABLE PACKER @ 7406 MD and 5550 TVD PACKER - OTIS WD PERMANENT PACKER @ 7799 MD and 5823 TVD SSSV - CAMCO DS NIPPLE @ 475 MD and 475 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut -in Subsequent to operation 303 1207 1987 — 180 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p' < Service r Stratigraphic r 16. Well Status after work: ,,,Oil 17 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce A 265 -6471 Email John.W.Peirce( conocoohillips.com Printed Name John Peirce Title Wells Engineer Signature 40, gt/ Phone: 265 -6471 Date • 1 b [2.611?.. .e. Form 10 -404 Revised 10/2012 S OCT 2 9 2O1t /0/21 7 4 " 4 / . /bubmit Original Only 2U -06 Well Work Summary DATE SUMMARY 7/20/12. DRIFTED TBG WITH 5' x 1.5" M. ENCOUNTERED ASPHALTENES At 6780' TO PATCH @ 7329' RKB. UNABLE TO WORK THROUGH TBG CUT @ 6761' RKB. SERVICED LEAKING SWAB VALVE TWICE, JOB SUSPENDED UNTIL SWAB CHANGED OUT. 7/26/12 MEASURED BHP @ 7622' RKB, GRADIENT STOP © 7478' SLM, IN PROGRESS 7/27/12 SET 2.75" ER TEST TOOL IN TOP OF ER PACKER © 7329' RKB, REPLACED 1.5" OV WITH SAME @ 5919' RKB, TESTED TBG WITH D & D HOLEFINDER, LEAK APPEARS TO BE BETWEEN 5940' RKB & 6798' RKB, IN PROGRESS 7/28/12 TESTED TBG WITH D & D TEST TOOL, LEAK APPEARS TO BE BETWEEN 6820' AND 6795' RKB, SWAPPED STA# 4 DV WITH SAME © 6797' RKB, REPEAT SAME TEST W/ HOLEFINDER AND CONFIRMED DV © 6797' RKB ( ER TEST TOOL IN HOLE FOR E -LINE LEAK DETECT ). IN PROGRESS. 8/3/12 T- LLR IS 6 GPM. 8/13/12 RIH W/ 24 ARM MIT CALIPER. LOG FROM TAG AT 7316' TO SURFACE. DATA SENT TO ANCHORAGE FOR PROCESSING. 8/18/12 RAN LEAK DETECT LOG WITH P/T /SPINNER TOOLS. LOG BASE TEMPERATURE PASS FROM SURFACE TO 7320'. FOUND LEAK AT 6804' RKB NEAR BOTTOM OF GLM #4., LITTLE RED PUMPED DOWN TUBING AT 0.5 BPM TAKING RETURNS FROM IA TO FLOWINE. FOUND WELL WAS FLOWING UP THRU THE STANDING VALVE (ER TEST TOOL) SET AT 7329' RKB. WELL FLUID WAS EXITING THRU THE LEAK AT 6804' RKB INTO THE IA. CLOSED IA AND DISCONTINUED LDL. 9/8/12 DRIFTED TBG WITH 35' 2" x 1 -7/8" TOOL STRING TO 6875' SLM. READY FOR GYRO. 9/14/12 PULLED ER TEST TOOL @ 7327' RKB. BRUSH'n FLUSH TBG IN PATCH AREA. DRIFTED TBG TO 6900' MD WITH 2.74" x 32' DUMMY PATCH. READY FOR E /L. 9/18/12 SET WEATHERFORD LOWER ER PACKER WITH MID E LEMENT SET DEPTH OF 6820'. CCL TO MID ELEMENT 9.9' CCL STOP DEPTH 6810.1'. 9/22/12 SWAB VALVE NOT HOLDING. STAND BY FOR VALVE CREW. WERE UNABLE TO SHOW UP DUE TO TRAINING. IN PROGRESS. 9/23/12 RAN 3 1/2 ER TEST TOOL, SET IN LOWER PACKER © 6820' RKB AND CMIT TO 2500 PSI ( PASS ). PULLED TEST TOOL. IN PROGRESS. 9/24/12 SET UPPER ER PACKER PATCH ASSY (OAL= 32.13') @ 6788' RKB: BLEED IA DOWN TO 300 PSI TO CONFIRM STINGER SEALED. RAN 3 1/2 ER TEST TOOL TO UPPER PACKER MIT -T 2500 PSI (PASS) COMPLETE. 9/25/12 PERFORMED GYRO SURVEY. LOGGED GYRO SURVEY FROM SURFACE TO 6750'. . KUP 0 2U -06 + EonocoPhitIips 11-4 Well Attributes Max Angle & MD TD AIHSka, Inc. Wel!bore API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) coomagrips 500292128200 KUPARUK RIVER UNIT PROD 50.02 7,000.00 8,286.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date SSSV: NIPPLE 20 9/29/2011 Last WO: 10/6/2003 41.60 3/14/1985 Well Conlg: - 20-06, 10/26/2012 11'.12'.33 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,047.0 8/24/2011 Rev Reason: REVISE 2008 PATCH ASSY osborl 10/26/2012 HANGER. 31 ., - ... ..4 ', Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd CONDUCTOR 16 15.062 38.0 105.0 105.0 62.50 11 WELDED • Cuing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,641.5 2,978.8 36.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 33.0 8,213.6 6,103.4 26.00 J -55 BTC CONDUCTOR, Tubing Strings 38 -105 Tubing Description String 0... String ID ... Top (560) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd Ur TUBING WO 3 1/2 2.992 31.1 7,653.8 5,721.4 9.30 L -80 EUE8RDMOD NIPPLE, 475 ar Completion Details I Top Depth (TVD) Top Intl Nomi... GAS LIFT, Top (ftKB) (6103) ( °) Item Description Comment ID (!n) 3,208 31.1 31.1 0.04 HANGER MCEVOY GEN III TUBING HANGER 3.500 -- 474.6 474.6 0.22 NIPPLE CAMCO DS LANDING NIPPLE 2.875 7,390.9 5,5392 46.91 LOCATOR BAKER LOCATOR 2.992 7,392.4 5,5402 46.90 PBR BAKER 80-40 PBR 2 SURFACE, 37 -3842 7,406.1 5,549.4 46.21 PACKER BAKER FHL RETRIEVABLE PACKER 2.970 7,491.0 5,608.1 46.00 NIPPLE CAMCO DS NIPPLE NO GO ... 111 GAS LIFT, 4,795 ,' =- 7,569.5 5,662.7 45.81 SLEEVE -C BAKER CMU SLIDING SLEEVE, CLOSED 4/3/2004 2.750 - 7,648.7 5,717.8 45.05 OVERSHOT BAKER POOR BOY OVERHSHOT, SWALLOWS 8' OF ORIGINAL 3.750 TUBING STUB GAS �.. Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 5519 TUBING Original 4 1/2 2.992 7,651.4 7,816.0 5,834.6 9.30 L -80 FL4S ® - , Completion Details Top Depth v., (ND) Top Inc] Nomi... PACKER, 8,758 Top (ftKB) (ftKB) (°) Item Description Comment ID (!n) GAS LIFT, N II 11 " II Top 5,738.1 45.24 BLAST RINGS BLAST RING (3) 2.992 PATCH, 6791 I 7,792.8 5,818.9 45.97 LOCATOR OTIS STRAIGHT SLOT LOCATOR 3.000 �.-. 7,794.3 5,819.9 45.98 SEALS SEALS 2.992 � ACKER, 6,817 7,799.3 5,823.4 46.02 PACKER OTIS WD PERMANENT PACKER 4.000 �� 7,801.8 5,824.6 46.03 ADAPTER PACKER ADAPTER 5.000 PACKER, 7,329 _ i 7,802.3 5,824.9 46.03 SBE OTIS SEAL BORE EXTENSION 4.000 $ GAS LIFT, . 1 7,807.3 5,828.4 46.07 NIPPLE CAMCO D NIPPLE NO GO **NOT USABLE, IDENTICAL PROFILE IN 2.750 7,335 CMU" PATCH, 7,332 PACKER, 7,347 I i1 -II 7,814.8 5,833.7 46.14 SOS OTIS SHEAR OUT SUB 3.015 lit! 7,815.5 5,834.2 46.14 WLEG OTIS WIRELINE ENTRY GUIDE 2.950 I 9 a s ,,in Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth LOCATOR, (NO) Top Inc' 7,391 r ` Top (ftKB) (RKB) (°) PER. 7,392 Description Comment Run Dale ID (]n) PACKER. 7,406 ` 6,788.0 5,143.7 48.26 PACKER WEATHERFORD ER PACKER 9/24/2012 1.750 6,790.9 5,145.6 48.28 PATCH SPACER PIPE & SNAP LATCH SEAL ASSEMBLY 9/24 /2012 1.992 IF 6,817.1 5,163.7 49.89 PACKER WEATHERFORD ER PACKER 9/18/2012 1.750 7,329.0 5,497.3 47.69 PACKER UPPER WEATHERFORD ER PACKER 9/8/2008 1.750 NIPPLE, 7,491 - 7,332.0 5,499.3 47.65 PATCH SPACER PIPE & SNAP LATCH SEAL ASSEMBLY 9/8/2008 1.750 II (OAL= 21.15) ir 7,347.0 5,509.5 47.46 PACKER ' LOWER WEATHERFORD ER PACKER 9/5/2008 1.750 SLEEVE -C, 7.570 7,901.0 5,893.6 47.40 FISH 1 1/2" DV Dropped Downhole 8/31 /1990 0.000 Mk • 8,044.0 5,990.2 48.10 FISH 3- 1 1/2" CV's Dropped 3 CV's in Rathole 5/27/1994 0.000 Mill Perforations & Slots OVERSHOT, Shot 7,649 I - Top (TVD) Btm (TVD) Dens Top (ftK8) 81m (ftKB) (RKB) MB) Zone Date (ah• -- Type Comment I I 7,700.0 7,754.0 5,754.0 5,791.8 C-4, UNIT B, 7/20/1991 12.0 IPERF DA 5" IPERF, 0, I 1 o_ 2U - 7,700 -7,754 I {f I - 7,851.0 7,866.0 5,859.0 5,869.4 A-4, 2U-06 7/20/1991 4.0 IPERF 180 deg. Phasing; DA 4" 7,866.0 7,914.0 5,869.4 5,902.4 A -3, 2U-06 7/20/1991 4.0 IPERF DA 4" PRODUCTION. 7,980.0 8,007.0 5,947.1 5,965.5 A -2, 2U -06 7/20/1991 4.0 IPERF DA 4" 7,774 LOCATOR, irMil Notes: General & Safety 7,793 End Date Annotation SEALS, 7,794 2/23/2004 NOTE: *CAUTION/WATCH PRESSURES ENTERING AREA OF OVERSHOT & CHEM CUTS** 8/18/2012 NOTE: TUBING LEAK @ 6804' RKB, FOUND w/ ELINE LDL PACKER. 7.799 _ ADAPTER, ER, 7,802 SBE, 7,802 MIND. NIPPLE. 7,807 B1 000 7.e,s Mandrel Details Top Depth Top Pon WLEG, 7,818,.... (ND) Intl OD Valve Latch Size TRO Run Stn Top MB) (ftKB) ( °) Make Mode! (in) Sery Type Type (i (psi) Run Date Com... 1 3,207.7 2,675.3 46.48 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,229.0 9/9/2008 7,851 7,866 2 4,795.2 3,779.9 47.57 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,226.0 9/9/2008 IPERF, 7,866 -7,914 3 5,919.1 4,544.6 47.57 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 7/27/2012 FISH, 7,901 - - 4 6,797.7 5,150.1 48.35 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 7/28/2012 5 7,334.5 5,501.0 47.62 CAMCO MMG 1 12 GAS LIFT PATCH RK 0.000 0.0 7/20/2008 IPERF, 7,880-8007 i 1. 6 7,774.5 5,806.1 45.86 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 8242003 FISH, 8,044 4 I PRODUCTION, 33E,214 TD, 8,286 • • 1`6 5-0 c / WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 2U -06 Run Date: 9/18/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2U -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21282 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: (11, Signed: 1 z- Y � 2A WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 21, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 2U -06 Run Date: 8/18/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2U -06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21282 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: \o 2 \ Z Signed: 1 "' 7 • - c • • ConocoPhillips RECEIVFD Alaska P.O. BOX 100360 OCT I 9 2012 ANCHORAGE, ALASKA 99510 -0360 AOGCC October 17, 2012 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 20 Anchorage, AK 99501 SCANNED JAN 2 Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2U-06 (PTD 185 -019) for a retrievable patch set in the tubing above the packer. Please call Kelly Lyons or myself @ 659 -7224 if you have any questions. Sincerely, Brent Rogers ConocoPhillips Problem Well Supervisor Enclosures tiLL;LillifLu 1 • STATE OF ALASKA OC, i 1 9 2012 ALIRA OIL AND GAS CONSERVATION COMFWION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well ;r' Rug Perf orations r Perforate r Other ✓ , Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program f Operat. Shutdown r Stimulate - Other °"" Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory J`°" _ 185 - 019 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50- 029 - 21282 -00 -- Op 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25644, ALK 2575 ' - 2U -06 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8286 feet Plugs (measured) None true vertical 6152 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 6788, 6791, 6817, 7329, 7406 true vertical 0 feet (true vertucal) 5144, 5146, 5163, 5497, 5550 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 105 105' 0 0 SURFACE 3605 12 3642 2979' 0 0 PRODUCTION 8181 7 8214 6103' 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7700 -7754, 7851 -7866, 7866 -7914, 7980 - 8007 True Vertical Depth: 5754 -5792, 5859 -5869, 5869 -5902, 5947 -5966 Tubing (size, grade, MD, and TVD) 3.5, L -80, 7815 MD, 5834 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 6788 MD and 5144 ND PATCH - SPACER PIPE & SNAP LATCH SEAL ASSEMBLY @ 6791 MD and 5146 ND PACKER - WEATHERFORD ER PACKER @ 6817 MD and 5163 ND PATCH - 2.74" ER PACKER PATCH ASSEMBLY @ 7329 MD and 5497 ND PACKER - BAKER FHL RETRIEVABLE PACKER @ 7406 MD and 5550 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development pr "` Service r Stratigraphic r 16. Well Status after work: — Oil Gas r" WDSPL r Daily Report of Well Operations X GSTOR WA GINJ WI ND r SUSP r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Brent Rogers /Kelly Lyons Printed Name nt Rogers Title Problem Well Supervisor Signature ...•-• Phone: 659 -7224 Date 10 -17 -12 Form 10 -404 Revised 11/2011 it MS OCT 19 20114 " / /#�' Submit Original Only • 2U -06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/18/12 SET WEATHERFORD LOWER ER PACKER WITH MID ELEMENT SET DEPTH OF 6820'. CCL TO MID ELEMENT 9.9' CCL STOP DEPTH 6810.1'. 09/23/12 RAN 3 1/2 ER TEST TOOL, SET IN LOWER PACKER @ 6820' RKB AND CMIT TO 2500 PSI ( PASS ). PULLED TEST TOOL. 09/24/12 SET UPPER ER PACKER PATCH ASSY (OAL= 32.13') @ 6788' RKB: BLEED IA DOWN TO 300 PSI TO CONFIRM STINGER SEALED. RAN 3 1/2 ER TEST TOOL TO UPPER PACKER MIT -T 2500 PSI (PASS) COMPLETE. 10/01/12 TIFL, Post- BOL- Passed. Initial T /I /O= 200/1325/950. Shut in well & lift gas.Shot IA FL @ ✓ 6797' station #4 DV. Stacked out TBG. T /I /O= 1100/1160/880. Bled IA 50mins. T /I /O= 1060/460/800. IA FL @ 6797'. Monitored 1 hr, IA FL @ 6797'. T /I /0= 1080/460/770. Summary !Set 32' Weatherford retrievable patch. TIFL passed following patch set. 2- '5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 15, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) : 2U -06 Run Date: 8/13/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2U -06 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21282 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 10 i Z Signed: • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 5, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 `:~%''~~ ~.~~ ~. t~ HOC Dear Mr. Maunder: ,--~ ~~_ ~; ~~ ~ Ak =a~ ~, "ir~~~',~ ~~~`~°, . ~-~ ~ I ~ ~~~~ - ®~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23`d , 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i~ ~~y~ L M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/5/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009 2U-05 185-018 40' 6.50 3'5" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23/2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1/18/2009 15.1 2/21/2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21 " 1 /24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1/24/2009 2.1 2!22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 Page 1 of 1 • • Maunder, Thomas E (DOA) from: Maunder, Thomas E (DOA) Sent: Thursday, October 02, 2008 12:29 PM To: 'NSK Well Integrity Proj'; 'NSK Problem Well Supv' Subject: 2U-06 (185-019) All, I have just finished reviewing the 404 for the tubing patch recently set in this well. In Block 11 (present well condition summary), some sort of entry should be made that there is a tubing patch in the well. I have hand entered that information an the 404. No need to send a new form. Call or message with any questions. Tom Maunder, PE AOGCC ~` r! ., i,, y: 5 Cc,.o;.. 10/2/2008 • a'~ (.... .r', '.. `y~ ~~ STATE OF ALASKA ~.. ~- ALASKA OIL AND GAS CONSERVATION COMMISS N ,~Q. REPORT OF SUNDRY WELL OPERid-~"f~`NS 1. operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other Q Patch Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnocoPhilhpS Alaska, InC. Development ~ Exploratory ^ 185-019 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21282-00• 7. KB Elevation (ft): 9. Well Name and Number. RKB 106' - 2U-06 ' 8. Property Designation: 10. Field/Pool(s): ADL0025644 ' Kuparuk River Field /Kuparuk Oil Pool 11, Present Well Condition Summary: Total Depth measured .8286' feet true vertical 6152' • feet Plugs (measured) Effective Depth measured 7901 feet Junk (measured). 7901 true vertical 5893 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 105' 16" 105' 105' SURFACE 3536' 9-5/8" 3642' 2979' PRODUCTION 8108' 7" 8214' 6104' ll__ ~~ ~J ~ ~ ~~ S~ ~ ~ ~~ Perforation depth: Measured depth: 7700-7754, 7851-786 6, 7866-7914, 7980-8007 true vertical depth: 5754-5792, 5859-5869, 5869-5902, 5947-5966 ~~~ 1~/~ Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7816' MD. Packers &SSSV (type & measured depth) PACKER =BAKER FHL PACKER = 7406' MD or 5550' TV D SSSV= NIPPLE SSSV= 475' 12. Stimulation or cement squeeze summary: Intervals treated (measured) wq Treatment descriptions including volumes used and final pressu re: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 602 1294 1012 998 196 Subsequent to operation 464 2404 884 830 228 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _Xe 16. Well Status after work: Oi10 •Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt N/A contact Martin Walters / Brent Rogers Printed Name Martin Walters Title Problem Wells Supervisor •. -- Signature ~ ~ - Phone:- 907-659-7224- Date- 09/20/08. - - - - Pre ared b Martin Walters 59-7224 ~~ ~~~~$ ~~ ~30•~ Form 10-404 Revised 04/2006 Submit Original Only • 2U-O6 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 7/18/2008 TAGGED @ 8084' RKB, EST. 77' RATHOLE. SET CATCHER @ 7556' SLM. PULLED OV @ 7335', GLVs @ 6798', 5919', 4795', 3208' RKB. SET GLVs Q 3208', 4795', OV (c~ 5919', DVs @ 6798', 7335' RKB. IN PROGRESS. 7/19/2008 PULLED EMPTY CATCHER @ 7556' SLM. HOLFINDER IDENTIFIED LEAK (a~ 7335' RKB. IN PROGRESS. 7/20/2008 TROUBLESHOOT GLM @ 7335' RKB. SET DV WITH WI PKG, TBG TEST FAILED. BRUSHED POCKET; SET EXTENDED PKG DV tQ 7335' RKB, TBG TEST FAILED. JOB SUSPENDED. 7/29/2008 MEASURE PRESSURE & TEMP 7335' RKB. SET 2.81" CA-2 PLUG 7491' RKB 7/30/2008 SET CATCHER SUB tQ 7491' RKB. SET DV'S @ 5919' 4795' & 3208' RKB. PULLED DMY VLV 7335 RKB POCKET OPEN 7/31/2008 8/14/2008 DISPLACED TBG/ IA WITH 260 BBLS DIESEL. SET 1.5" SWELL PACKER Cad 7335' RKB. PULLED AVA CATCHER (a~ 7491' RKB. (***DO NOT PUMP ON OR DRAW DWN TBG/ IA FOR 14 DAYS***). CMIT TxIA @ 1500 psi -passed. CMIT TxIA @ 2000 psi -passed. CMIT TxIA Ct~ 2500 psi - assed. MITIA @ 1500 psi -failed. MITIA @ 2000 psi -failed. MITIA C~ 2500 psi -failed. MITT @ 1000 psi -failed. MITT @ 1500 psi -failed. MITT @ 2000 psi -failed. MITT Q 2500 si -failed. - ' 8/18/2008 GAUGED TBG TO 2.80" TO PLUG 7491' RKB. PULLED PRONG. IN PROGRESS. 8/19/2008 D 2 - L G BODY 7491' RK .LOG PDS CALIPER TO 7816' RKB TO SURFACE DATA GOOD COMPLETE 8/25/2008 RAN EXPRO DOWN HOLE VIDEO. TOOK VIDEO OF SWELL PACKER AT GLM#5 AND TUBING OVERSHOT. GLM #5 LEAKING OPPOSITE SWELL PACKER IN PITTING[GORROSION. OVERSHOT IS ABOVE AND DID NOT SWALLOW GUT TUBING STUB 8/27/2008 SET 2.81" CS-A2 PLUG @ 7491' RKB. DRAW TBG FROM 1650#»»1250#. IA TRACKED FROM 1400#»»925#. WELL READY FOR E-LINE LDL 8/29/2008 PERFORMED SPINNER/TEMPERATURE/GRADIO LEAK DETECT LOG. RESULTS: SINGLE LEAK INDENTIFIED IN POCKET OF GLM #5. THIS IS A CORROSION LEAK OPPOSITE THE SWELL PACKER DUMMY BASED ON VIDEO RUN FROM 08/25/2008. 9/2/2008 PULL 2.81" CS-A2 PLUG 7491' RKB. JOB IN PROGRESS. 9/3/2008 DRIFT 22' X 2.74" TO 7400' SLM. WELL READY FOR E-LINE. 9/5/2008 SET WEATHERFORD ER PACKER CENTER OF ELEMENT AT 7350'. 9/8/2008 TEST LOWER PACKER, SET UPPER ER PACKER ,SPACER PIPE, AND SNAP LATCH ASSEMBLY (21.15' OAL W/ 1.75 ID) IN TOP OF LOWER PACKER @ 7350' RKB. UPPER ER PACKER IS SET _ 7329' RKB (THIS PATCH ASSEMBLY COVERS GLM Cat 7335' RKB ). ATTEMPTED MITIA (FAILED) RAN ECLIPSE TEST TOOL AND SET IN ER PACKER 7329' RKB. MIT TBG. TO 3000 PSI (PASSED) PULLED TEST TOOL. IN PROGRESS. 9/9/2008 MITIA 3000 PSI, PASSED. PULLED DVS AND INSTALLED GLVs @ 3208', 4795', AND OV 5919' RKB. COMPLETE. Summary Set Weatherford Retreivable atch from 7329' - 7350' 09/15/08 J -1 ~~i~l{~~~~~~i Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~~ `,iras _ . ' ~;~.a~ ~.~'~~~ fi ..~..t Log Description N0.4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1 C-172A 11978478 PRODUCTION PROFILE ~- 08/19/08 1 1 1C-172A 12080429 GLS/FBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY 08/20/08 1 1 3C-17 11996657 SCMT ~ - /(n 9iL/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY ~ a p~-p~~ ~~0~//~ 08/27/08 1 1 2U-06 12080428 LDL _p 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE d =p 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31!08 1 1 2D-07 11975790 INJECTION PROFILE - ~ Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE ~ /p 09/05/08 1 1 iC-174 12096539 INJECTION PROFILE - ' ~} p 09/07/08 1 1 2H-12 12096540 PRODUCTION PROFILE ~ ~ 09/09/08 1 1 30-01 11975792 LDL ~-U 09/09/08 1 1 3F-10 11975789 LDL ~ 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • WELL Lf1G S TRANSMfTTAL 3.. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 • RE : Cased Hole/Open Hoie/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa>G (907) 245-8952 1) Caliper Report 19-Aug-08 211-06 1 Report / EDF 50-0291282-00 2) _, ~e~t1N~~ ~Ep ~. fl 2008 /~S'-b!9 ~~~ l Y ". ~ ~~ ~~_ Signed : Date Print Name: CG~-~~~_ ~~ .~- ~ ~ ~ ~•~ PROACTIVE DUIGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)2{5-89b1 Fax: (907-248-88952 E-MAIL: pdsanchoraaeCn~memorylogcom WEBSITE:www.memorylog.com C:\Docume,ds and Settings\OwnertDesktap\14ansmit_Conoco.doc 1 ~~ • • Memory Multi~inger Caliper Log Results Summary Company: _. ConoaoPhillips Alaska, Inc. Welt: 2l!-~ Log Date: August 19, 2008 Fiell: Kuparuk Log No.: 8706 State: Alaska Run No.: 1 API No.: 50-029-21282-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 EUE 8RD Top Log Irttvl1.: Surface Plpe1 Use: Tubing Bot. Log Intvll.: 7,809 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage Inspection '' COMMENTS This caliper data is tied into the WLEG ~ 7,809' (FEND). ' This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing appears to be in good to poor condition, with three joints with holes recorded between Production Mandrel Station #6 and the Baker Overshot. A 3-D log plot of the caliper recordings across this interval is included in this report. Multiple hales are recorded in the tubing stub (7,659'), joint 238 (7,750'}, and pup joint 238.1 (7,762'). Cross-sectional wall loss of 579 is recorded in pup joint 238.1 (7,762'). Deposits/Possible Pipe Deformation restrict the I.D. to 2.30" in the tubing stub 235.3 (7,657'). No other significant I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATION5 Multiple Holes (100%} Jt. 235.3 ~ 7,659 Ft. (MD) Hole (100°~) Jt. 238 ~ 7,750 Ft. (MD) Multiple Holes (100%) Jt. 238.1 @ 7,762 Ft. (MD) Isolated pitting (43%) Jt. 238.7 ~ 7,807 Ft. (MD) No other significant wall penetrations (> 19%} are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Multiple Holes (57%) Jt. 238.1LaD Hole (26%) Jt 238 No other significant areas ofcross-sectional wall loss (> 14%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS 7,762 Ft. (MD) 7,750 Ft, (MD) Deposits/Possible Pipe Deformation Minimum I.D. = 2.30" Jt. 235.3 (cD No other significant l.D. restrictions are recorded. c~ e.':i91~~~1.~ J ~ ~ Xs c3 2I1~i8 i~ 7,657 Ft (MD} Field Engineer K. Miller Analyst: C. Waldrop Witness: C. Fitrpatridc ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~~S~-~i ~` ~~~9~ • • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2U-06 Date : August 19, 2008 Description : Detail of Caliper Recordings Across Holes Above Production Mandrel #6 • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (14.5' - 7808.9') Well: 2U-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 19, 2008 ^ Approx. Tool De viation ^ A pprox. Borehol e Profil e 1 17 25 -- 799 50 1570 75 `~ '' 2362 GLM 1 3151 O L ~ 125 v 3965 ~ ~ .5 Z t Y N C_ Q- GLM 2 ° 4751 ~ 175 -- 5570 GLM 3 200 6386 GLM 4 225 7204 GLM 5 Prod 6 238.8 7809 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 238.8 C .] PDS Report Overview ~. S. Body Region Analysis Well: 2UA6 Survey Date: August 19, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldr~ Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower (en. 3.5 ins 9.3 f -55 EUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 8$% Number of 'oints anal sed total = 266 pene. 1 154 107 0 1 3 loss 70 192 2 1 1 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion conosion corrosion ible hole Number of 'oints dama ed total = 4 1 0 0 0 3 Damage Profile (°k wall) w penetration body c_,,~ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 Prod6 Bottorn of Survey = 238.8 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: 2U-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 19, 2008 Joint No. )t. Depth (Ft.) I'c~n. Uln~•t (ln,.) Pen. Body (Ins.) P~~n. °i, ~Ic•t•~I I u~~ ~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 14 t) 0.01 G I 2.96 PUP 1 17 t I 0.02 7 2.92 2 50 t 1 0.02 7 2.95 2.1 82 t ~ 0.02 ') 1 2.93 PUP 2. 92 ~! 0.02 ') _' 2.91 PUP 2.3 98 i~ 0.0 ~) _' 2.90 PUP 2.4 102 ti 0.02 ~) ~ 2.9 PUP 3 108 t ~ 0.0 7 2.91 4 140 U 0.02 I 2.93 5 173 t) 0.02 t3 _' 2.93 6 204 U 0.02 7 f 2.93 7 236 a 0.02 t3 2.94 8 267 U 0.02 ti I 2.95 9 299 t~ 0.02 ~~ 2.93 10 31 a 0. 3 11 I 2.93 11 363 t) 0.02 9 1 2.94 12 395 U 0.01 5 1 2.93 13 426 l) 0.0 7 ? 2.93 13.1 456 t) 0 U t~ 2.88 Camco D Ni le 14 458 t~ 0.02 ') I 2.90 15 489 t ~ 0.02 ~ ~ ~t 2.93 16 521 U 0.01 ~ 2.91 17 553 t) 0.04 17 (, 2.90 18 584 t) 0.04 14 ~1 2.91 19 616 U 0.02 ~) =t 2.91 20 647 U 0.03 11 2.91 1 678 t) 0.02 9 s 2.91 22 707 O 0.03 1 Z 2 2.88 23 738 U 0.03 10 1 .91 24 769 ~ ~ 0.01 -1 I 2.92 25 799 a 0.01 (~ I 2.94 26 830 ti 0.04 L, ~., 2.92 27 61 U 0.04 14 1 2.93 28 893 a 0.03 I u ~' 2.92 29 924 0 0.03 12 ~' 2.8 30 956 l~ 0.03 1 ~! 2.93 31 987 t) 0.04 I ~, 2.90 32 1017 t) 0.04 I ~ [, 2.92 33 1046 U 0.02 t3 ~ 2.93 34 1075 U 0.02 ~> I 2.93 35 1107 (~ 0.05 lt?' 0 2.91 36 1138 U 0.03 t a 2.92 37 1169 l) 0.03 1(~ ~' 2.88 38 1201 a 0.03 11 a 2.90 9 1 32 t~ 3 11 ~ 1 40 1261 i) 0.03 1 I ~ 2.90 41 1292 t~ 0.02 ti U 2.91 42 1323 a 0.03 I Z 1 2.91 43 1353 t~ 0.0 11 _' 2.90 44 1385 U 0.04 14 ~1 2.93 _ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: 2U-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 19, 2008 Joint No. Jt. Depth (Ft) I'~~n. IJl~tic~t Un,.l Pen. Body (Ins.) f'c~n. °4> ~1~~t.il log, ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 45 141 t) 0.03 I 1 2.91 46 1445 t) 0.03 1 ~ U 2.90 47 1476 t) 0.04 I4 (~ 2.90 48 1508 t) 0.02 7 I 2.90 49 1538 O 0.02 4 ? .95 50 1570 t) 0.01 ' .97 51 1601 U 0.03 1~I ~ 2.93 52 1633 (t 0.03 I I 4 2.92 Lt. De osits. 53 1665 a 0.01 ~~ > 2.94 54 1697 U 0.03 1 ~ _' 2.92 55 1728 ! ~ 0.03 1 U _' 2.94 56 1760 t) 0.05 I t1 .t 2.90 Lt. De osi 57 1791 ll 0.03 11 2.95 58 1823 t) 0.03 I ~ i 2.94 Lt. De osits. 59 1855 U 0.03 1 ~ 2.95 6 1886 U 0.0 1 I I 2.95 61 1918 a 0.04 I ;~ I 2.92 62 1950 (~ 0.03 I I I .97 63 1983 a 0.01 5 I 2.92 64 2015 a 0.01 6 _' 2.94 65 2045 t) 0.03 1 a _' 2.92 Lt. De osits. 66 2077 c1 0.03 13 ~ 2.94 67 2108 l) 0.04 1 a 2.94 68 2140 (! 0.04 15 _' 2.93 69 2171 O 0.03 I 1 ~ 2.94 70 2203 (i 0.03 I ~ 2.94 71 2235 a 0.04 I ~ (, .93 72 2266 U 0.02 _' 2.96 73 298 ~) 0.04 1 ~ -i 2.94 74 2330 O 0.05 1 ti ~i 2.91 Ton Mash. Lt. De sits. 75 2362 U 0.04 1 i 5 2.91 76 2393 t) 0.02 I 2.94 77 2424 U 0.04 I: b 2.90 78 2455 U 0.04 1 f5 b 2.90 Ton Mash. 79 2487 O 0.04 1 E~ ~ 2.96 80 2519 U 0.01 (~ ~' 2.95 81 2551 c) 0.01 t, i) 2.95 82 2582 c) 0.01 .' 2 2.94 83 2613 O 0.03 I t> ? 2.93 84 2647 U 0.01 4 2.92 85 2678 a 0.01 _' ~ 2.9 86 2710 i) 0.05 1~) 2.91 87 2741 !~ 0.01 4 2.94 88 2773 (~ 0.01 5 2.96 89 2804 t) 0.03 1:3 ~ .95 90 2836 U 0.02 ~) _' 2.95 91 2867 ii 0.02 ~) ~ 2.95 92 2898 a 0.01 5 2.94 93 2930 ~:) 0.01 i I 2.95 94 2962 0.02 i! 2.95 ®Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: 2U-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, tnc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 19, 2008 Joint No. Jt. Depth (Ft.) Nen. Ul~sc~t (lns) Pen. Body (Ins.) Pen. % Metal loss °4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 2993 i? 0.02 9 1 2.94 96 3025 U 0.03 1 1 .! 2 92 97 3057 tt 0.04 14 4 .92 98 3089 It .04 14 7 2.89 To Mash. Lt. e sits. 99 3120 l l 0.03 1 Z .97 100 3151 U 0 03 1 ~~ I 2.95 1 0.1 3183 I> 0.02 ti I 2.91 PUP 10 3191 tl 0 U O N A GLM 1 Latch ~ 1:00 100.3 3200 U 0.02 t4 ! 2.92 P P 101 3208 It 0.01 ~ I 2.96 0 3239 U 0.0 12 2 2.95 103 3271 U 0.01 E, _' .93 104 3303 U 0.01 i~ 4 .92 105 3334 t) 0.01 ~ 1 2.96 106 3365 U 0.01 5 I 2.94 107 3396 ~) 0.02 ~+ 2.95 108 3428 t) 0.0 7 1 3 109 3460 II 0.02 ~) _' 2.9 1 0 491 U 0.05 1 ~) 5 .93 on Mash. Lt. De its. 111 3522 t) 0.0 8 t~ .93 1 3554 tl 0.04 1 G ~' 2.9 113 3585 c I 0.01 ~ ~ .95 114 3617 U 0.02 ~i t .95 115 3649 0 0.04 15 2.92 Lt. De osits. U 15 9 117 3712 U 0.02 ~) ~' 2.95 118 3744 U 0.03 11 4 .93 119 3776 U 0.04 16 ; 2.94 1 0 3808 i) 0.02 f~ ? 2.95 121 3838 ! I 0.03 1 ~ ~ 2.92 122 3870 U 0.02 ~ ~ 2. 4 123 3902 t) 0.03 lu 4 2.95 1 4 3934 U 0.01 (, I 2.94 125 3965 t1 0.02 ~~ ? 2.94 126 3996 U 0.04 I t~ ~ 2. 1 Ton M sh. 127 4029 t) 0.01 5 ' 2.95 28 4060 O 0.03 11 1 .96 129 4091 I t 0.03 1 u ~ 2.89 130 4124 tl 0.04 1 ~ 2.93 Ton M sh. 131 4156 tl 0.02 I 2.95 13 4186 tl 0.01 .96 133 4217 U 0.01 Z 1 2.95 134 4249 a 0.04 14 ~' 2.9 135 4281 tl 0.02 7 I 2.96 36 4312 U 0.01 'i 1 .95 137 4343 U 0.02 7 4 2.92 1 8 4374 tt 0.03 1 2.91 139 4406 a 0.02 7 s 2.92 140 44 6 t ~ 0.02 t9 2.91 141 4467 a 0.02 ~) I 2.89 _ Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: 2U-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 19, 2008 Joint No. Jt. Depth (Ft.) Pe°n. UF,;~~t Iln~.) Pen. Body (Ins.) P~~n. %> Mc~i,il loss °'~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 142 4499 ~) 0.03 I 1 ~ .90 143 4531 t) 0.0 7 -l 2.91 144 45 1 O 0.01 6 <' .94 145 4594 a 0. 3 I t) .9 146 4624 a 0.0 I5 i 2.94 Ton Mash. 147 4657 U 0.0 ~ 2 2.94 148 4 88 ~) 0.01 _' 2.95 149 4720 U 0.02 ti ? 2.9 150 4751 U 0.04 17 ~ 2.93 Ton M sh. Lt. De sits 150.1 47 3 u 0.0 11 -1 2.89 PUP 1 0. 479 U 0 l) t~ N A GLM 2 tch ®10:30 1 4801 (t 0.02 ~~ -1 2.90 P P 151 4812 ~) 0.03 13 2 93 152 4844 U 0.03 I U <' 2.94 153 4876 U 0.04 16 5 2.9 e osits. 154 4908 U 0.03 1 _t 1 2. 2 155 4940 U 0.02 is I 2.93 1 6 4970 t) 0.03 tt~ -t 2.9 157 500 U 0.02 ~) 2. 158 5033 U 0.03 l a I 2.9 9 5065 I) 0.01 0 1 2. 1 160 5096 U 0.02 ~) ~ 2.93 161 1 8 U 0.04 1~ 291 162 5160 U 0.03 I t) 3 2.95 1 3 5191 t) .0 .94 164 5223 U 0.02 i 1 2.95 165 5254 ~) 0.01 r, ~> 2.94 166 5285 )) 0.01 ~ 2 2.94 167 5317 U 0.04 I ~ ~ 2.9 168 5349 c) 0.03 I ; 2.93 169 5381 O 0.02 ~ 95 170 5413 O 0.02 ~~ I 2.94 17 5444 U 0.04 14 2.91 172 5475 ~) 0.04 15 4 2.92 173 5507 U 0.04 17 ? 2.90 L e osits. 174 5539 t) 0.02 7 I 2.96 175 5570 U 0.0 0 ? 2.9 176 5602 U 0.04 15 _' 2.91 17 5634 ~.) 0.02 7 ~ .9 178 5665 ~) 0.01 5 ' 2.91 79 5697 U 0.03 11 -t 2.92 180 5729 U 0.03 1 ; 2.95 181 5760 U 0.0 ' .93 182 5790 l) 0.01 ~' I 2.93 1 3 5822 U .01 > ' 2. 5 184 5854 i) 0.02 ~) i 2.91 185 588 c) .03 1 1 5 2.92 185.1 5918 ~) 0.03 lu 1 2.91 PUP 185. 592 t) 0 i ~ ~ ? N A LM 3 Latch ®8: 0 185 3 5936 t) 0.02 2.88 PUP Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf )-55 EUE SRD Well: 2U-06 Body Wall: 0.254 in field: Kuparuk Upset Wall: 0.254 in Cornpany: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 19, 2008 Joint No. Jt. Depth (ft.) I'e~n. t Il,c~t (Ins.) Pen. Body (Ins.) Pen. °ro tilr~t.~l I oss °~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 186 5946 +) 0.01 t> I .94 187 5978 +~ 0.03 1 ~ 2.93 188 6009 tt 0.02 I .93 189 6041 ++ 0 05 I ~i 2.94 190 6072 tt 0.01 ? I .9 191 6103 U 0.03 13 -4 2. 2 192 6135 +? 0.01 5 I 2.94 193 6166 U 0.03 1 _ t 2.90 . De osits. 194 6198 U 0.02 - 2 2.94 19 622 l) 0.02 ~3 1 2.95 196 6261 tt 0.02 ~) _' 94 197 6293 a 0. 3 1 ' a 2.91 Lt a osits. 98 6323 +t 0.03 I ; I 2. 4 199 6355 +~ 0.03 I1 .93 00 6386 ! t 0.04 I b 2.93 201 6421 +t 0. 2 ti 3 2.91 02 6452 l + 0.0 I t3 ' 2.90 20 6481 +t 0.02 ~) 1 2.90 204 6513 ++ 0.01 ~ -~ 2.90 205 6544 11 0.03 13 4 06 576 c) 0.04 15 4 2.90 207 6608 tt 0.02 2.91 208 6639 tl 0.01 5 ? .94 209 6671 0 0.01 6 1 2.95 10 6702 U 0.02 ' .9 211 6735 ++ 0.03 12 _' 2.93 212 6765 a 0.00 1 ' 2.96 212.1 6798 0 0.02 b 1 2.90 PUP Lt. De sits. 212. 6809 U 0 u U N A GLM 4 Latch ®4:00 212.3 6816 it 0.02 ti 2 2.93 PUP 213 6827 tt 0.01 6 2 2.93 214 6858 a 0.01 2 ? 2.92 21 6890 u 0 14 5 2.90 216 6921 tt 0.01 6 ~ 2.91 217 69 2 U 0.01 ! 1 2.94 218 6985 U 0.02 ~ 1 2.94 219 7017 t) 0.01 5 ~ .90 220 7048 i) 0.02 t3 -1 2.92 1 7079 tt 0.01 4 1 2.90 222 7110 i ~ 0.03 l 0 3 2.89 223 7142 tt 0.03 1tt I 2.94 224 7173 U 0.02 i _' 2.95 225 7204 +~ 0.03 12 7 2.9 226 7236 rt 0.01 G I 2.96 27 7268 a 0.03 I U .94 228 7300 ~ ~ 0.02 FS ? 2.89 228.1 7331 i l 0.01 5 ~ 2.89 PUP 228.2 7342 tt 0 +) U N A GLM 5 Latch ~ 10:30 228.3 7350 +~ 0.02 ~+ .92 PUP 229 7360 ~ ~ 0.03 I ~ ! 2.90 Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf )-55 EUE 8RD Well: 2U-06 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: August 19, 2008 Joint No. Jt. Depth (Ft.) I'~~n. ill~se~t Iln~.) Pen. Body (Ins.) Nc~n. % Metal I oss °~~> Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 22 .1 7391 U D 0 O 2.99 Baker PBR 29.2 73 6 0 0.02 £3 ~ 2.95 PUP 229.3 7 9 t) 0 fl tt 2.97 Baker FH Packe 229.4 7412 O 0.01 -1 2.88 PUP 2 9.5 7419 a 0. 2 ti 1 2.88 UP 23 7425 U 0.03 1:3 `; 2.92 231 74 6 t ~ 0.03 1 ~ ra 2.90 To Mash. 231.1 748 a 0.0 8 ~ .9 PUP 231.2 7495 U U U 2.81 C m XN-Ni le 2 1.3 7497 U 0.04 5 t) .85 PUP 232 7505 U 0. 12 ~ 2.89 233 7537 U 0.04 18 5 2.89 Lt. D osits. 33.1 7569 U 0.03 12 I 2.88 PUP 233. 7574 U 0 U i) 2.75 B k r CMU Sleeve 233.3 7578 U 0.03 10 2.88 PUP 2 4 7584 U 0.03 12 .89 235 7615 U 0.03 1? 2.92 35.1 7647 O OA fi I 2.91 PUP 235. 7654 U 0 U U 3.75 Baker Poor Bo Overshot 235. 7657 U.b7 0.77 100 I ~ 2 30 tub. Multi le of ! De osits Pi e Deformati 2 6 7669 t) 0.04 14 I 2.76 Lt. De osits. 37 7701 t) 0.0 I 2.94 238 7730 U 0.69 1OU _'t. 2.92 Hoe! - - 238.1 7760 U 0.33 1 t)U 5 ~ 2.93 PUP Multi le Holes! - - - - 238. 7765 U 0 0 tt N A Production Mandrel 6 L t ®10:00 238.3 7774 U 0 03 13 ! 2.94 PUP 238.4 7785 t) 0 0 t) 4.00 Otis WD Packer 238.5 7795 ~~ 0.01 4 _' 2.96 PUP 238.6 7801 t? 0 i1 U 2.75 amco XN D-Ni le 238.7 7803 rt 0.11 -l3 I I 2.96 PUP Isolated ittin . 2 8.8 7809 +) 0 +) tt 2.99 WL G _ Penetration Body Metal Loss Body Page 6 PDS Report Cross Sections ~= .~~ , Well: 2U-06 Survey Date: August 19, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf J-55 EUE 8RD __ __ _ Analyst: _ C. Waldrop Cross Section for Joint 235.3 at depth 7658.533 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 94 Tool deviation = 43 ° Finger 14 Penetration = 0.768 ins Multiple Holes 0.77 ins = 100% Wall Penetration HIGH SIDE = UP r~ • Cross Sections page 1 ~ ~S PDS Report Cross Sections We-l: 2U-06 Survey Date: August 19, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf 1-55 EUE 8RD Analyst: C. Waldrop Cross Section for Joint 238 at depth 7749.7 Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 76 Tool deviation = 44 ° Finger 17 Penetration = 0.69 ins Hole 0.70 ins = 100% Wall Penetration High Side = UP Cross Sections page 2 ~~ PDS Report Cross Sections 1 Well: 2U-06 Survey Date: August 19, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f -55 EUE 8RD Anal st: C. Waldro Cross Section for Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 43 Tooi deviation = 48 ° Joint 238.1 at depth 7762.293 ft • r~ Finger 16 Penetration = 0.332 ins Multiple Holes 0.33 ins = 100% Wall Penetration HIGH SIDE = UP ~ ~ ~ ~ ~ ~ ~ ~ a~ ~ ~ ~ ~ ~ ~ ~ ! ~ ~ Cross Sections page 3 ~S PDS Report Cross Sections 1 Well: ZU-06 Survey Date: August 19, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3,5 ins 9.3 f -55 EUE SRD Anal st: C. Waldro Cross Section for Joint 235.3 at depth 7657.463 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 Tool deviation = 43 ° Finger 22 Projection = -0.509 ins Deposits /Possible Pipe Deformation Minimum t.D. = 2.30 ins HIGH SIDE = UP • • Cross Sections page 4 KUP 2U-06 ConocoPhillips ` wen ntt -wutes ' ~ ~ .,. , - - WeBtipt AW 500292 NWI 128200 Nell dBta KUPARUK RIVER UNIT PROD NS Malamun tincNtndon ( ) 50.02 ~d R) T 8,286.0 _ - a_~. rte,, , ~ ~ Conttent NIPPLE H S (ppn) 130 7/1/2008 Last WO: a pq 10/6/2003 41.60 Release 3/14/1985 ~ Last T 8.084.0 BM Ye 7/18f2008 Rev Reason: GLV C/O, SET PLUG. SWELL PKG IN GLM Date &112008 Cetsi s Set Deplft coNOUCTOR, D evi oD o M TaP Opel mKe1 1~1 Ib~q t]ade Top tlrcod 7a6 CONDUCT OR 16 15.062 0.0 105. 0 105.0 62. 0 H~10 SURFACE 95!8 8.765 0.0 3.642. 0 2,979.1 36.00 J-55 NIPPLE, 475 ODU T IO 8.1 1 0.0 8,214. 0 B, 3. 26.00 J-55 Tubl Stri s GAS LIFT, 3,208 n6111g D escdptlm OD pp D pq Tap el C!f ptK~ Srt Depdt Wt (Pos111) trade Tap 7lread TUBING 31/2 2.992 0.0 7.816.0 5,834.6 9.30 J-55 EUE SRD suRFACE. Other In Hole A ll Jewe l : T ut-in Ru n 8 RtNrie vab Fish etC 3,662 Top ufp tlon . Run a ID 475.0 NIPPLE CAMCO'DS' NIPPLE set 10/82003 10/62003 2.875 cASLIFT 3 208 0 GAS LIFT CAMCO/MMG/1 5/ IRK!//Contin ent STA 7130 2 920 4,795 , . . : . 4.795.0 GAS U COIMMGl1. DMY KlII Comm ent STA 2 7/302008 2. ZO 5.919.0 GAS LIFT CAMCO/M 1.5IDMY/RK/// Cortvn ent: A 3 7/30/2008 2.920 Gas s1s 6.798.0 GAS LIFT CAMCO/ MCV1.51 MY/RKI// Corran ent: STA4 7/182008 2.920 7,335.0 GAS LIFT C O/M 1.5/SWELP K!// C omment STA 5 7202008 2.920 7,392.0 PBR BAKER80/40 PBR set 10AG2003 10/62003 2.990 GAS LIFT, 6,x96 7,406.0 PACKER BAKER HL IEVABLE ACKE R Set 10/62 3 t01T/2003 2.970 7.491.0 NIPPLE CAMCO NO GO NIPPLE WMO GO PROFILE, sat 10/62 1016/ 3 2.812 GAS LIFT, 7,491.0 PLUG 2. 1"CA-2 PLUG 7292008 0.000 r ass 7,569.0 SLEEVE- C BA R MU set 10/6103. CLOSED 4/32004 101612003 2.750 ,649.0 OVE H OT BAKER P BOY OVERSHOT set 1 - SWALLOWS 8' OF TUBIN G 11Y6l2W3 3.750 STUB OF ORIGINAL COMPLETION P~2, 7 392 7, 1.0 TBG C TBG CUT 81312003 8/312003 2.992 7,6 B RI NG Blast Ring 423/1985 3.500 7,767.0 PRODUC TION CAMCO/MMG- 1.510 NIRIW/ Cor mlerlt: A R INJ PKG - FR 8242003 2. PACKER. r 406 ORIGINAL COMPLETION STA 6 7, 0.0 LOCATO R l~ 423/1986 2.992 NIPPLE, ~a91 7 770 0 TBG C TBG C 8/31 8/J12003 2 992 PLUG. ],491 , . . 7,787.0 PACKER Otis 1985 4.000 7,801.0 NIPP Camoo'D' Nlpple NO GO 423/198b 2.750 '•NOT USABLE DUE TO IDENTICAL PROFLLE UPHOLE IN CMIJ•' sLEEVESL6e 7, .0 7 809 0 503 WLEG Otis WIR NE UIDE 423/1985 423!1985 2.992 2 . . I . ovERSnor, ~ 7,901.0 FISH 1 12' DV Dropped Dovmltole 8/31/1990 ~ sea 8.044.0 FISH 3 - 1 12' s Dropped 3 CV'sn Rat tlole 527!1994 TRG cur, pef/OWI IOrIf that ],661 Top IT11W ehn (T11D) Deus Top etie IRKS) Peel Zone (*~-• Date Dot®e~ 7.7 .0 7. 54.0 ,754.0 .79 .8 IPERF Cam, UNIT 2U-06 B, 12.0 72011991 DA 5" ansrm ~ 7,851.0 7, .0 5,859.0 5,8894 1PERF A~,21}08 4.0 7 0/1991 180 deg. Pn DA 4• avrg; IPERF. ],Iao-~ ]s4 7,866.0 7,914.0 ,869.4 5,902.4 P F A-3, 2U-06 4.0 720/1991 DA 4' 7.980.0 8.007.0 5,947.1 5, .5 IPERF A-2, 2U-06 4.0 72011991 DA 4' PRODUCTION. ].767 Notes: O aneral 8. EJItl a le LOCATOR. Tno 2/23/2004 NO TE 'CAUTIONNJAT H PRESSURES ENTE RING ARFfL OF OVERSHOT 6 HEM CUTS" reG cur, r,no PACKER, 7,787 NIPPLE. ],601 GD$.78a9 VvLEG. ],809 IPERF, 7,651-7,866 IPERF. r,886-7,916 FISH, r,991 IPERF, 7,980A,0a7 FISH, 8,014 PRODUCTION, 8,214 TD.8186 2U-06 (PTD 1850190) Report of failed TIFL Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, July 08, 2008 3:48 PM !~nA To: Maunder, Thomas E (DOA); Regg, James B (DOA) `~"~~ Cc: NSK Problem Well Supv Subject: 2U-06 (PTD 1850190) Report of failed TIFL Attachments: 2U-06 schematic.pdf; 2U-06 90 day TIO plot.jpg Tom, Jim Page 1 of 1 Kuparuk gas lifted producer 2U-06 (PTD 1850190) failed a diagnostic TIFL on 07/07/08 and was added to the weekly SCP report. The TIO prior to the TIFL was 250/900/680. A leaking GLV is suspected. Slickline will troubleshoot the GLV's and repair if possible. Attached is a 90 day TIO plot and a schematic. «2U-06 schematic.pdf» «2U-06 90 day TIO plot.jpg» Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~N~a SAP ~. 2D08 8/29/2008 KRU 2U-06 PTD 185-019 T/UO Plot - 2U-06 zooo 1500 d 1000 +. ............................,.,.......,,Ft. ............................................_.............................,.~..~ ..........e....~ 200 150 E 100 ~ C t 500 50 0 o ~ 08-Apr-08 21-Apr-08 04-May-08 17-May-08 30-May-08 Date 12-Jun-08 25-Jun-08 ~~~ /`~ Goncacc~Phill"rps Alaska, TUBING (a781s, OD:3.500, ID:2.992) Blast Ring (7677-7768, _ OD:4.500) _....._.. Perf _ (7851-7914) Perf (7866-7914) ~j `i ~ 1_ i' ~_ ~ ~ - InC KRU 2U-06 Zu-os API: 500292128200 Well T e: PROD An le TS: 45 d 7700 SSSV T e: NIPPLE Ori Com letion: 3/14/1985 An le TD: 48 de 8286 Annular Fluid: Last W/O: 10/6/2003 Rev Reason: TAG FILL Reference Lo Ref Lo Date: Last U date: 11/1/2006 Last Ta : 8069 TD: 8286 ftKB Last Ta Date: 10/17/2006 Max Hole An le: 50 d 7000 Casin Strin -CASINGS. Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 105 105 62.50 H-40 SURFACE 9.625 0 3642 2979 36.00 J-55 PRODUCTION 7.000 0 8214 6104 26.00 J-55 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 7816 5835 9.30 J-55 EUE 8RD Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 7700 - 7754 5754 - 5792 C-4,UNIT B 54 12 7/20/1991 IPERF DA 5" 7851 - 7866 5859 - 5869 A-4 15 4 7/20/1991 IPERF 180 d . Phasin ; DA 4" 7866 - 7914 5869 - 5902 A-3 48 8 7/20/1991 IPERF DA 4" 7980 - 8007 5947 - 5965 A-2 27 4 7/20/1991 IPERF DA 4" Gas -Lift Mandrels/Valve s St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3208 2675 CAMCO MMG GLV 1.5 0,188 1233 10/11/200 2 4795 3780 CAMCO MMG GLV 1.5 0.250 1275 10/11/200 3 5919 4545 CAMCO MMG GLV 1.5 0.250 1272 10/11/200 4 6798 5150 CAMCO MMG GLV 1.5 0.250 1265 10/10/200 5 7335 5501 CAMCO MMG OV 1.5 0.250 0 10/10/200 Production Mandrels/Valves - - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 6 7767 5801 Camco MMG-2 OPEN 1.5 RK 0.000 0 8/24/2003 1 i. water in" pkg -from Ori final Com letion Other lu s, a ui ., etc.. -.JEWELRY De th TVD T e Descri tion ID 475 475 NIP CAMCO 'DS' NIPPLE set 10/6/2003 2.875 7392 5540 PBR BAKER 80/40 PBR set 10/6/2003 2.990 7406 5550 PACKER BAKER FHL RETRIEVABLE PACKER set 10/6/2003 2.970 7491 5608 NIP CAMCO NO GO NIPPLE W/NO GO PROFILE, set 10/6/2003 2.812 7569 5662 SLEEVE-C BAKER CMU set 10/6/03, CLOSED 4/3/2004 2.750 7649 5718 OVERSHOT BAKER POOR BOY OVERSHOT set 10/6/2003 - SWALLOWS 8' OF TUBING STUB OF ORIGINAL COMPLETION --- 3.750 Other lu s, a ul , etc..-ORIGINAL JEWELRY De th TVD T e Descri tion ID 7661 5727 TBG CUT TBG CUT 8/31/2003 2.992 7677 5738 Blast Rin 3.500 7770 5803 Locator 2.992 7770 5803 TBG CUT TBG CUT 8/31/2003 2.992 7787 5815 PKR Otis 'W D' 4.000 7801 5825 NIP Camco'D' Nipple NO GO **NOT USABLE DUE TO IDENTICAL PROFILE UPHOLE IN CMU** 2.750 7809 5830 SOS Otis 2.992 7809 5830 WLEG WIRELINE GUIDE 2.992 fish - FISH De th Descri tion Comment 7901 1 1/2" DV Dro ed Downhole 8044 3 - 1 1/2" CV's Dro ed 3 CV's in Rathole General Notes Date Note 2/23/2004 ** USE EXTREME CAUTION W HEN ENTERING AREA BETWEEN OVERSHOT AND SECONDARY CHEMICAL CUTS -WATCH PRESSURES. REFER TO WSRs FOR 2/10/04 AND 2/23/2004 ** Schlumberger Schlumberger -DCS 2.525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # /9t¡.Þé)7¿ 1D-11 I ~-"';¿'ð1 3A-11 , ~ CJf tf 2U-06 l¡¡$z~ ~ 3A-15 1'~j -o?? 3C-12 772 -ð I? 1A-15 , q "2.d 1 L-09 {)-e(/J 10922472 10922478 10922477 10922479 10922482 10922481 10802915 Log Description Date INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PROD PROFILEIDEFT (REDO-WELL SKETCH) 10/11/04 10/16/04 10/15/04 10/16/04 10/19/04 10/18/04 07/26/04 ... / /,,; I Î SCANNED DEC 2: 8 2004 SIGNûltßv- .f/~~. NO. 3241 /ðS-o{/ 1 0/22/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: BL DATE: Kuparuk Color CD 1 1 1 1 1 1 1 It) /¿/tf z- Please sign and return 0 e opy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ,-,,' I "-" ConoCOPhillips Mike Moone¥ Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 5, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2U-06 (APD # 185-019) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 2U-06. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Moon~y Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED 1 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [] Suspend [] Operation Shutdown [~] Perforate [~ Variance r-'] Annular Disp. [] Alter Casing ~ Repair Well r-~ Plug Perforations ~] Stimulate r-~ Time Extension ['--] Other Change Approved Program [ Pull Tubing ~] Perforate New Pool r'-'] Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [~ Exploratory ~ 185-019 / 3. Address: Stratigraphic ["-] Service [~ 6. APl Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21282-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 106' 2U-06 8. Property Designation: 10. Field/Pool(s): ADL 25644, ALK 2575 Kuparuk Oil Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8286' feet true vertical 6152' feet Plugs (measured) 7828' Effective Depth measured 7828' feet Junk (measured) true vertical 5843' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 105' 105' S U RFACE 3601' 9-5/8" 3642' 2979' PRODUCTION 8178' 7" 8214' 6103' Perforation depth: Measured depth: 7700'-7754', 7851'-7914', 7980'-8007' ~ECE~v~D true vertical depth: 5754'-5792', 5859'-5902', 5947'-5965' Tubing (size, grade, and measured depth) 3-1/2", J-55, 7816' MD. z~,~.. ~.?, ~. ~ '~.. "' ~'; '.' t,',: ,'..: .~,~,..~ .,.,.~;.!;?., ~'~.i" '.',~'::,.~ ...,., ..... Packers & SSSV (type & measured depth) pkr=- Baker 'FHL', Otis WD pkr= 7406' · 7787' SSSV= Camco Landing Nipple Landing nipple = 475' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casin,q Pressure Tubin,q Pressure Prior to well operation SI Subsequent to operation 246 578 1479 226 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run __ Exploratory E~] Development [~] Service [ Daily Report of Well Operations __X 16. Well Status after proposed work: Oil["~ Gas [--'~ WAG[]--{ GINJ [--'] WINJ ~ WDSPL['"] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: I Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader Signature ~, ~ Phone Date ///~"/'~d ~ ~f~/'~-/~'~ Prepared by $~qrop~Al~r~-Ora~_~_~6_.~-.4(~ 12 Form 10-404 Revised 2/2003 · SUBMIT IN DUPLIOATE ConocoPhillips Alaska Page 1 of 14' Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From- To HoUrs Code Sub Code Phase DescriptiOn of: Operations 9/9/2003 18:00 - 00:00 6.00 MOVE MOVE MOVE Released rig from 2U-10 @ 18:00 hrs. Move Nabors 3S to 2U-06. 9/10/2003 00:00- 03:00 3.00 MOVE MOVE MOVE Move off 2U-10 to 2U-06. 03:00 - 05:00 2.00 MOVE RURD MOVE Spot modules - tree crooked - RU Nabors 3S 05:00 - 05:30 0.50 WELCTL SFTY DECOMP Safety Meeting/pre spud meeting with the crew and engineer. Discussed well plan and plan forward. 05:30 - 06:00 0.50 WELCTL NUND DECOMP Accept rig at 05:30. Begin loading pits with 10.6# brine. Checked annulus gauge and had 650 psi on it. Tubing had 975 psi. Wells group left 200 psi on it. Fluid level dropped or gas influx? 06:00- 09:00 3,00 WELCTL NUND DECOMP RU lubricator, pull BPV. Press on tubing 975 psi. Shot fluid level on tbg and IA. 425' on tubing, surface on IA. 09:00 - 13:00 4.00 WELCTL NUND DECOMP Rig up 500 bbl Tiger Tank and hard line from choke to kill well to. 13:00 - 18:00 5.00 WELCTL KILL DECOMP Held pre-job safety meeting before well kill. Test lines to 2000 psi. Pumped 10.6 ppg mud down tubing taking returns to Tiger tank. Pumped at 2.5 BPM. Tubing press. 1650 Annulus press 1000 psi. Holding backpress to prevent sand plug flowback. Returns showing gas, crude and brine. After pumping tubing volume (65 bbls) lost returns. Opened choke, lowered tubing pressure to 900 psi got ~mmediate returns. Continued to drop tubing pressure to 700 psi. annulus press 240 psi. Contiued pumping, pumped total of 430 bbls of 10.6 ppg mud, returns 10.1 ppg. Low on mud volume, shut down ~umps monitor press. Tubing press 50 psi Annulus 220. 18:00 - 18:30 0.50 WELCTL SFTY DECOMP Held pre-spud meeting with 2nd crew and Engineer. 18:30 - 00:00 5,50 WELCTL COND DECOMP Building mud to 11.1# in Prudhoe. Annulus and tubing pressures equalized through tree seal leaks @ 140 psi. 9/11/2003 00:00 - 06:00 6.00 WELCTL CIRC DECOMP Circulate 11.1# mud down tubing and up annulus @ 2.5 bpm following kil sheet. Pumped a total of 530 bbls of 11.0# finally getting around to surface. Well drinking @ 12 bbls/hour during the job and increased to 20 bbls/hour toward the end. Shut down pumping to monitor pressure. 06:00 - 09:30 3.50 WELCTL OBSV DECOMP Monitor well. Tubing pressure 50 psi Annulus pressure small vacuum. 09:30 - 10:30 1.00 WELCTL KILL DECOMP Switch hoses around, fill annulus. It took 2.4 bbls to fill, press, came up 'to 400 psi on annulus as soon as we caught fluid and the tubing press. came up immediately to 100 psi. Shut down, monitor well. Bled press off. Tubing 0 Annulus small vacuum. After 1 hr tbg 50 psi annulus still small vacuum. 10:30 - 14:00 3.50 WELCTL KILL DECOMP Filled annulus w/1/4 bbl and 0 press on tubing and no returns. Brought ;)ress up to 300 psi @ 1/2 BPM. Pumped 3 bbls away with no returns at tubing. Shut down pump: Annulus 0 Tubing 0. 14:00 - 17:00 3.00 WELCTL NUND DECOMP Install BPV thru lubricator. ND tree. 17:00 - 00:00 7.00 WELCTL NUND DECOMP NU BOPE - Pull BPV - some pressure underneath (approx. 10 psi) - ran two way check. Begin test of BOPE system. 9/12/2003 00:00 - 04:00 4.00 WELCTL BOPE DECOMP Continue BOP test - BOP test complete with all componets passing. 04:00 - 06:00 2.00 WELCTL BOPE DECOMP Attempted to pull two way check valve used for BOP testing. Pressure under two way check filled up stack with fluid and would not quit blowing gas. Unable to pull two way check without lubricator. Called Prudhoe for valve crew. Waiting On permission for them to help support Kuparuk. 0530 hrs received permission from BP management. Valve crew on the hook from Prudhoe. Procured a lubricator from Nabors 9ES. 06:00 - 09:00 3.00 WELCTL OBSV DECOMP Wait on VECO valve crew to pull two-way check. 09:00- 12:00 3.00 WELCTL OBSV DECOMP Rig up lubricator, pull two-way check valve. Tubing pressure 70 psi. Ann. press, o Bled pressure off thru choke to 0 well flowed back 1 bbl. Shut in press built up to 25 psi in 5 min. 150 psi in 30 min. Rigged Printed: 10/17/2003 11:16:03 AM ConocoPhillips Alaska Page 2 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Sub Phase DeScriPtion of OperationS Date: From'To Hours Code Code 9/12/2003 09:00- 12:00 3.00 WELCTL OBSV DECOMP down VECO lubricator. :12:00 - 16:00 4.00 WELCTL CIRC DECOMP Rigged up to circulate. Conditioned mud to 11.1ppg. Pumped down tubing taking returns thru gas buster. Got immediate returns. Pumped 295 bbls. @3.5 BPM. with 1000 psi. Mud returning had large amounts of air, breaking out in pits. No LEL. Shut down monitor well. Tubing 0 Annulus 0. 16:00 - 18:00 2.00 WELCTL OBSV DECOMP Monitor well to confirm dead. Tubing 0 Annulus 0. 18:00 - 19:00 1.00 WELCTL NUND DECOMP Picked up landing it. screwed into hanger. Backed out lock down screws. One of the lock down screws twisted off. 19:00 - 00:00 5.00 WELCTL NUND DECOMP Nipple down stack - grind off lock down screw pin end inside hanger flange. Found a second sheared off LDS and had to grind it off also. Grinding in progress. 9/13/2003 00:00- 04:00 4.00 WELLSF NUND DECOMP Grind down second sheared off LDS. 04:00 - 05:00 1.00 WELCTL BOPE DECOMP Nipple up stack - Pulled BPV - Ran two way check - Close and test blind rams and flange break to 250 psi and then 4000 psi for 15 min. Test good. Pulled two way check. 05:00 - 06:15 1.25 FISH PULL DECOMP Screw into hanger with landing joint - check all LDS. Pull up on tubing to 114K - worked pipe up and down numerous times for an hour attempting to pull out of SBR. Call Eline to chemical cut. Continue to work pipe and let sit with a 114K (not including block weight) bind on it. Well bubbling some but no gain or loss in fluid, level. 06:15 - 14:30 8.25 FISH ELIN DECOMP RU SWS E-Line, tie new head with big line. Held pre-job safety meeting with both crews. RIH with string shot. Slow rate going in because of 11.1 mud, (2000' per/hr). Tied in with e-line. Shot string shot mid jt above the SBR and below GLM #9 @ 7503' to 7490'. 14:30- 17:00 2.50 FISH ELIN DECOMP POOH with e-line. 17:00 - 22:00 5.00 FISH ELIN DECOMP Rig up chemical cutter and RIH at approx. 4000'//hr. Tied in and shot - good indication. Cut tubing at 7500'. POOH w/chem cutter. Stood back Eline equipment and tied onto pipe. Pulled clean off the cut @ 60K- rig down Eline equipment and rig up to circulate hole. 22:00 - 00:00 2.00 WELCTL CIRC DECOMP Circulate well down tubing @ 2 1/2 bpm rates and 720 psi on tubing - immediate returns. Mud is foamy & aerated. Losses approx. 13 bbls. Circulated out 4424' of gas kick that was in the casing. LEL meters at 56% in pits and 100% below rotary table. Shut down circ to monitor hole. 9/14/2003 00:00 - 05:00 5.00 WELCTL CIRC DECOMP Continue to monitor hole after circulating out 4426' of heavily gas entrained mud in the casing. Circulated another bottoms up to make certain all the gas was out. Almost three surface to surface circulations completed. Gas still entrained in mud but much better now. Mix and , pump a dry job pill. Prep to pull tubing out of the hole. 05:00 - 07:15 2.25 FISH PULL DECOMP Lay down landing joint and tubing hanger. Pump addition two bbls for dry job. Start pulling tubing and laying down in pipe shed. Pulled 29 jts, experience 2 bbl gain. Shut down monitor well. No movement well dead. Checked gas monitor 0 LEL. Pull 9 more jts (38 total)gained 1-1/2bbls. When pulling slow the well shows small amount of flow (swabbing), when stop there is no flow. 07:15 - 07:30 0.25 WELCTL OBSV DECOMP Monitor well. No flow. Well dead. 07:30 - 10:00 2.50 WELCTL CIRC DECOMP Circulate bottoms up 3.5 BPM @ 650 psi. 11.2 mud all the way around. We did get 26 bbls of 11.4 mud at the end of our circulating, cleared up :to 11.2 ppg. 10:00 - 13:00 3.00 FISH PULL DECOMP i Pull 4 jts gain 1-1/2 bbl. shut down fill hole. Pulled 3 more jts gained 1-1/2 bbls shut down filled hole, monitoring well each time before pulling. This time tubing flowing small amount. Printed: 10/17/2003 11:16:03 AM ConocoPhillips Alaska Page 3 of 14 OPerations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From,To ::HoUrs Code Sub PhaSe Description Of Operations Code 9/14/2003 13:00 - 16:00 3.00 WELCTL ClRC DECOMP Circulate 567 bbls in attempt to get mud cleaned up and wash anything off of the SSSV. Increased MW to 11.5 ppg cimulated good completely around at 6105' Pumped dry job 27 bbls. Monitor well, dead 16:00 - 18:00 2.00 FISH PULL ~ DECOMP Pulled 11 more its up to SSSV, no swabbing action gained only 1-1/2 bbls. Remove SSSV and control line. Retreived 35 SS bands, I band left in the hole. 18:00 - 19:00 1.00 WELCTL OBSV DECOMP Monitor well while rigging down control line spooler. Appeared to be static with no losses or gains. 19:00 - 00:00 5.00 FISH PULL DECOMP . Pulled 20 joints at a joint every 2+ minutes - influxed 1 bbl gain - should have had a 2 bbl loss -- total of 3 bbl swab into tubing. Stop and confer I with engineering. Pulled two joints while watching the hole static - hole is slightly swabbing during test pull. Decided to run back in hole with drillpipe crossed over to tubing to circulate well from bottoms up. 9/15/2003 00:00 - 04:30 4.50 WELCTL TRIP DECOMP Rig up drillpipe equipment - RIH with drillpipe to bottom @ 7464' (just above tbg. cut depth). Normal displacement volume to the pits. 04:30 - 10:00 5.50 WELCTL CIRC DECOMP Start pumping approx. 3 bpm rates down tubing and up annulus to circ out any entrained gas. Found gas at 3400' down casing to 7450' (90 bbls into pump job - gas to the surface). Continued circulation and started mud conditioning (caustic, defoamer, water and barite) to lower gel strength after circulating out gas entrained mud. 11.5# mud both in and out. 10:00 - 11:00 1.00 FISH CIRC DECOMP Pumped 100 bbls of reconditioned 11.5 ppg mud with YP down to 29. 11:00 - 00:00 13.00 FISH PULL DECOMP Attempt to POOH with tubing & drill pipe without swabbing. Fluid in tubing would not fall as we pulled - pumped 15 bbl dry job. POOH slowlly, hole displacement correct for 40 stands of drill pipe. Tubing fluid level would not fall as we pulled. Pumped 15 bbl dry job. Continue to POOH, displacement numbers correct. All 233 joints pulled - chemical cut stub end looked good. Rig up for drillpipe. Lost a total of 4.5 bbls over displacement volumes. Fluid currently falling slowly when hole was static. 9/16/2003 00:00 - 08:00 8.00 WELLSI; TRIP DECOMP Rig up drilpipe spinners, tongs and elevators. MU Baker 7" Retrievamatic packer. RIH with packer on 3.5" drillpipe to attempt to test casing for integrity. RIH very slowly to avoid surging and pre-mature packer setting. Normal displacement volumes to pits for first 80 joints (2600'). Well drinking fluid very slowly when static. 08:00 - 16:45 8.75 WELLSI= TRIP DECOMP Continue RIH with Packer. Tubing overflowing while running in. Pump dry job. Continue RIH. Going very slow to keep from surging hole or running fluid over the top of the pipe. Displacements look good. 16:45 - 17:15 0.50 WELLSF; TRIP DECOMP Tag down at 7491' RKB (Doyon 9). Set down 5K on stub. Chemical cut was at 7500' RKB. Could be strapping difference. Tag looks solid. More like metal than fill. PU 2' above stub. Set Retrievamatic packer. 17:15 - 18:00 0.75 WELLSI; DEQT DECOMP Pressure test casing to 1970 psi. Pressure dropped to 1950 psi in 30 min. Good test. Bleed off pressure. Release packer. 18:00 - 20:00 2.00 WELLSI; CIRC DECOMP RU to reverse circulate. Circ surface to surface (253 bbls) pump rate @ 3 bpm, starting pressure 1500 psi and ending pressure 950 psi. No gas in returns. Slight oil film seen upon btms up.. Mud in good shape, 11.6#, YP=27, Vis = 50. 20:00 - 21:00 1.00 WELLSI; CIRC DECOMP Layed down JT# 236 of DP into pipe shed and pumped a 20 bbl dry job 13.7# down the DP. 21:00 - 00:00 3.00 WELLSI; TRIP DECOMP Started tripping pipe standing back doubles in the derrick. Removed 60 stands (120 jts). Lost 8 bbls of fluid in addition to pipe displacement. Printed: 10/17/2003 11:16:03 AM ConocoPhilliPs Alaska Page 4 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: "Rig Name: Nabors 3S Rig Number: Date From To HOurs ~Code Sub Phase Description of Operations ' COde 9/16/2003 21:00 - 00:00 3.00 WELLSF!TRIP DECOMP Continued tripping out of the hole 9/17/2003 00:00 - 04:00 4.00 WELLSF TRIP DECOMP Continued tripping OOH pulling doubles and standing back in the derrick. On surface with Baker Retrievamatic Packer. Very minimal marks on the bottom of the packer (possibly slight metal marks). Total fluid losses during trip after pipe displacement was 24 bbls. Losses app: 3.5 bph. 04:00 - 06:00 2.00 WELLSF PULD DECOMP Layed down drillpipe Jt#1 in the pipeshed. Layed down Baker Packer. Slight marks on bottom of packer where stub was tagged. No obvious sign of damage. Clean up floor. 06:00 - 11:30 5.50 FISH RURD DECOMP PU kelly, upper & lower kelly cock valves. PU swivel. MU kelly hose. 11:30 - 16:30 5.00 FISH RURD DECOMP PT kelly cock valves & saver sub. Upper kelly cock valve failed. We could not get valve to close. LD upper kelly cock. No replacement valve is on site. Begin search for replacement valve. PT kelly & lower :kelly cock valve. Lower kelly cock valve will not PT. Replace valve and retest. 2nd valve failed. Replace valve again. 16:30 - 17:00 0.50 FISH RURD DECOMP PT kelly, kelly hose, and 3rd lower kelly cock to 250/4000 psi. Good test. Set back kelly in rat hole. Located upper kelly cock valve on Nordic 2. Valve is on location. It is not tested, but it is available if needed. 17:00 - 18:30 1.50 FISH RURD DECOMP Clean up rig floor. LD tongs. PU bails and elevators for drill pipe. 18:30 - 20:45 2.25 FISH PULD DECOMP Make up Baker Fishing BHA w/overshot, 20:45 - 00:00 3.25 FISH TRIP DECOMP Trip in the hole with Fishing BHA & 3.5" drillpipe. Gained an additional 5 bbls beyond pipe displacement during trip to current depth. Continued tripping in the hole. 9/18/2003 00:00 - 02:45 2.75 FISH TRIP DECOMP Completed trip in the hole with drillpipe & fishing assembly. Postioned overshot 1 joint off top of fish for circulation. 16 bbl pit gain beyond pipe displacement. 02:45 - 04:20 1.58 FISH CIRC DECOMP Reverse circulated hole surface to surface. Pump rate @ 3 BPM, initial pressure 1600 psi and final pressure 650 psi. Circulated a total of 276 bbls. 11.5# and 11.5# coming out. YP = 17 & Vis = 45. Had to add water to the mud for conditioning. 04:20 - 04:55 0.58 FISH TRIP DECOMP Started pumping conventionally down the drillpipe @ 1 BPM monitoring pressure, lowered overshot onto the stub, washing over as it was lowered. Intially it set down on top of the stub. Had to pick up and rotate to get over the stub. The overshot assembly only appeared to swallow 4' of the stub before bottoming out or sitting down. Shut down pumping. 04:55 - 05:20 0.42 FISH JAR DECOMP Bumped up and down a few times only pulling 110K (7K over). Pulled up to 120K and bled Jars down some. started jarring on fish 135K (32K over) approximately 5 hits. Straight pulling up to 160K (57K over) 05:20 - 05:30 0.17 FISH JAR DECOMP Continued Jarring on Fish worked up to 150K (47K over) Straight pulling up to 165K (62K over). Hitting a lick every minute. 05:30 - 06:15 0.75 FISH JAR DECOMP Continued Jarring on Fish worked up to 165K (62K over). Saw a little more movement when bumper jars opened 06:15 - 07:15 1.00 FISH JAR DECOMP Continued Jarring on Fish worked up to 170K (67K over). 07:15 - 07:35 0.33 FISH JAR DECOMP Pressure up on drill pipe to 1200 psi. Jar up one time. Close jars and PU. Fish started moving up hole. Continue pulling up fish dragging at about 125K. Picked up 24' to next tool joint. It appears we have the SBR and packer. 07:35 - 10:30 2.92 FISH CIRC DECOMP Rig up to circulate the long way. Break circulation and get returns to surface 1.6 BPM at 870 psi. Shut down and rig up to reverse circulate. Annulus pressured up to 1200 psi and held pressure. Cannot circulate by the packer. Decide to circulate bottoms up the long way to ensure no gas is below the packer. Begin pumping down the drill pipe at 1.6 Printed: 10/17/2003 11:16:03 AM COnocoPhillips Alaska Page5 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: :Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of OPerationS Date From-To Hours Code Code 9/18/2003 07:35 - 10:30 2.92 FISH ClRC DECOMP BPM and 870 psi. Getting good returns. 0 pit gain/loss. Circulate 1-1/2 bottoms up. No loss/no gain. No gas in returns. Slight oil film on shaker. Circulate until 11.5# in/out. SD pump. 10:30 - 10:45 0.25 WELCTL OBSV ,DECOMP Observe well. Fluid level dropped 1'in 15 min. 10:45 - 12:00 1.25 FISH JAR DECOMP Break out top joint. Break out pump in sub. MU joint back in string. Start jarring on fish up to 60K over string weight. Pull up to 85K over string weight after each lick. Small amount of movement upward. No down movement. LD 1 joint. 12:00 - 13:00 1.00 FISH ClRC DECOMP RU to circulate. Start pumping at 25 spm. Pressure went up to 870 psi and then started dropping off. Increase rate to 48 spm at 280 psi. Start pulling on pipe. Pipe moving free at string weight of 105K. SD pump and continue to pull. Packer pulling tight between 160K and 110K. Pull up to next tool joint. Break out joint and LD pump in sub. MU joint back in string. 13:00 - 14:45 1.75 FISH JAR DECOMP PU on pipe. Continue jarring. Getting small amount of movement. Work top tool joint to derrick board. 14:45 - 18:20 3.58 FISH JAR DECOMP Rig up to circulate. Cannot pump long way or reverse. Continue to jar on fish. Pressure up on drill pipe to assist jarring. Vary pressure between 0 psi and 1500 psi. Small amount of movement upward. Attempt to beat fish down with bumper sub and collars. Fish would not move down. Continue jarring with varying pressures on drill pipe up to 1500 psi. Jarring up to 75K over string weight. Work next tool joint to rig floor with 85K over pull. 18:20 - 20:00 1.67 FISH ClRC DECOMP Fish came free. PU 15' and pressure bleed off. Able to circulate. RIH circulating. Pressured up on way down. It looks like the SBR barrel came free. Can see drag going up and down on the slickstick. Top of slickstick at +/- 7404' RKB (3S). PU above slickstick and reverse circulate. Circulated bottoms up twice 11.6# in and out. Mud coming back @ bottoms up showed signs of sand intrained in it. 20:00 - 20:35 0.58 FISH ClRC DECOMP Pumped a dry job down the drillpipe 13.2# (18 bbls) and monitored hole for returns or losses. Hole looked good to begin trip. 20:35 - 22:10 1.58 FISH TRIP DECOMP Trip drillpipe OOH, 103K pick up weight off bottom. Had 13 stands out of the hole and noticed a 19 bbls influx. Appears to have been swabbed in. Decided to trip drillpipe back in the hole and circulate. 22:10 - 22:45 0.58 FISH TRIP DECOMP Trip drillpipe back down to top of fish to circulate out the influx 22:45 - 23:10 0.42 FISH ClRC DECOMP Reverse circulate @ 3 BPM. At bottoms up small amount of gas coming back with fluid and fluid weight dropped down to between 9.0# - 10.0#. After 15 bbls mud weight came back up to 11.7#. Gas continued to come back with mud for another 20 bbls, averaged 250 LEL. 23:10 - 00:00 0.83 FISH ClRC DECOMP Continue to reverse circulate and condition mud, pump rate @ 3 BPM and circulating pressure @ 620 psi. 210 bbls into the circulation. Mud weights 11.6# going in and 11.5# coming out. Vis = 43, YP = 20. !9/19/2003 00:00 - 02:00 2.00 FISH ClRC DECOMP Continued reverse circulating 3 BPM and 620 psi circulation pressure.. 2 complete surface to surface circulations plus an additional bottoms up for a total of 532 bbls. Mud looks good 11.5#+ in and out. toward the end of the circulation the mud pump was down temporarily for about 10 rains. 02:00 - 02:30 0.50 FISH ClRC DECOMP Monitored Hole with the pump shutdown. Well is still slightly flowing. 02:30 - 04:15 1.75 FISH CIRC DECOMP Kicked pump back on and started reverse circulating again @ 3 BPM and 620 psi cim pressure. Raise the mud weight up to 11.7#. circulated 330 bbls around getting good 11.7# in and 11.7# out. 04:15 - 04:35 0.33 FISH CIRC 'DECOMP Shutdown the pump and monitored the hole. Hole is static. 04:35 - 04:45 0.17 FISH CIRC ~DECOMP Pumped dry job down the drillpipe 19 bbls of 13.4#. Broke out the head Printed: 10/17/2003 11:16:03 AM ConocoPhillips Alaska Page 6 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Sub Phase Description of Operations Date From- To HOurs Code Code: 9/19/2003 04:35 - 04:45 0.17 FISH CIRC DECOMP pin and monitored hole. Well is static and ready for trip. 04:45 - 06:30 1.75 FISH TRIP DECOMP Start tripping drillpipe OOH, pulling in Iow to avoid swabbing. Pulled 20 stands and monitored hole, well is still static. 06:30 - 13:00 6.50 FISH TRIP DECOMP Continue tripping drillpipe OOH. Notify AOGCC of upcoming BOP test at 0950. Stand back collars. LD fishing tools and fish. Recovered 15' cut off joint and SBR barrel. 15' jt corkscrewed probably due to fishing operations. Top of cut joint recovered with tubing string was not bent. Formation sand and carbolite packed inside overshot. No fill between overshot and SBR. Overshot engaged about 4' down on cut joint. Fill above SBR may have prevented overshot from travelling further down the joint. Close blind rams. Clean up rig floor. Hole took 7 bbls over calculated displacement on trip out of hole. Monitor well. Fluid level is holding steady. '13:00 - 14:00 1.00 FISH SFTY DECOMP New day crew on location. Hold Pre-Spud meeting with crew, Co. man, and both Toolpushers. Discuss workover to date, upcoming work, and well control issues. 14:00 - 15:30 1.50 WELCTL EQRP DECOMP Replace Upper Kelly Cock with new valve. 15:30 - 17:45 2.25 WELCTL BOPE DECOMP Witnessing of BOP test waived by Chuck Scheve with AOGCC. Test upper kelly cock and lower kelly cock valves to 250/4000 psi. BD test equipment. Set back kelly. Clear floor of tools for changing upper kelly cock. 17:45- 18:00 0.25 WELCTL SFTY DECOMP Pre-job safety meeting. Discuss BOP testing procedures. New crew members that have not tested BOP's on this rig. 18:00 - 19:00 1.00 WELCTL BOPE DECOMP Run test plug. Attempt to test BOP's. Seal is leaking on test plug. Get new seal headed this way from warehouse. Observe well while changing seal. Slight trickle of fluid coming out of well down flowline. Close choke and kill lines. Flow did not decrease. 19:00 - 21:45 2.75 FISH PULD DECOMP , Prep floor for running BHA. Discuss situation with Wells Team Leader and AOGCC. Decide to get pipe on bottom to raise mud weight 0.5 ppg. Get approval from AOGCC to do BOP test when out of hole with fish. PU overshot for slickstick with 4.75" spiral grapple and packoff. Run washover shoe below overshot. Cannot run extensions above overshot because ID is smaller than 4.75". Stack is full of water from attempted BOP test. Fill stack with mud. Flowback stopped. MU bumper sub, jars, drill collars, and accelerator. 21:45 - 00:00 2.25 FISH TRIP DECOMP Well is still static. Trip in with BHA on 3.5" drill pipe. 40 stands in at mdnight. 1 bbl gain over pipe displacement. Monitored hole and continued tripping in with drill pipe. 9/20/2003 00:00 - 05:30 5.50 FISH TRIP DECOMP Continued tripping in the hole w/3.5" drill pipe & fishing BHA. Well started to slightly flow after 65 stands run and continued thru the rest of the trip. 111 stands in the hole, total gain during trip was 29 bbls. Prepared floor to circulate well. 05:30 - 06:05 0.58 FISH CIRC DECOMP Picked up head pin andl lined up pump to reverse circulate. Brought pump on @ 3 bpm, initial circulating pressure 1050 psi. Begin bringing mud weight up to 12.2# in the pits. 06:05 - 09:30 3.42 FISH CIRC DECOMP Pump rate @ 3 BPM, circ pressure @ 1100 psi. At bottoms up started getting a small amount of gas in the returns, registered 84 LEL. Mud weight on bottoms up 10.5# coming back. Continued to circulate and weight up. After 2-1/2 bottoms up 12.2# in/out. Circulating reverse at 173 spin (3 bpm) and 770 psi. Get slow pump rates: 50 spm - 250 psi, 120 spm - 430 psi. SD pump. 09:30- 09:45 0.25 WELCTI OBSV DECOMP Observe well. No flow or loss. 09:45 - 10:15 0.50 FISH WASH DECOMP Up wt=100K. Down wt=67K. Break out top jt. MU stand .112. Break Printed: 10/17/2003 11:16:03 AM ConocoPhillips AlaSka Page 7 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From To HoUrs COde Sub Phase DesCriPtion of Operations Code 9/20/2003 09:45 - 10:15 0.50 FISH WASH DECOMP circulation the long way 43 spm at 210 psi. Circulate down. No indication of fill. MU single jt. Circ down 43 spm at 210 psi. Engage fish 3' in on single. Packoff is at 7423' RKB. Top of fish was previously noted at 7404' RKB. This would have been the case if the first overshot had engaged the fish all the way down the cut off joint which it did not. Fish has not moved. Pressured up to 500 psi as packoff engaged fish. SD pump. Bleed off pressure. 10:15- 11:45 1.50 FISH JAR DECOMP Setdown to50K. PU and fire jars at 130K. Pull upto 175K and then 190K. Slack off to 50K. 1' deeper on down stroke. Pressure up on drill pipe to 880 psi. Jar at 175K. No movement. Pressure up to 1100 psi. Bleeding off slightly. Jar at 175K 2 times picking up to 190K. 1" movement up. Jar 10 times at 180K without picking up afterwards. Good jar licks. No movement. On last hit weight fell off to 65K. PU free. Up weight 103K. Set down and try to engage fish. Set down approx. 5" higher than before. PU free. Set down. Pressure up to 740 psi. PU until pressure bleeds off. 11:45 - 13:25 1.67, FISH CIRC DECOMP Line up to reverse circulate. Begin pumping at 173 spm and 870 psi. 100 psi higher than at end of weight up circulation. Good amount of formation sand and frac sand at bottoms up. Circulating pressure started falling off. Continue circulating waiting on returns to clean up. Circulate a total of 300 bbls which is over 1 surface to surface volume. Slight amount of solids in returns. Drain possum belly. Some sand in bottom, but no metal. 13:25 - 14:00 0.58 WELCTL OBSV DECOMP Monitor well. No flow or gain. LD top joint. Break out head pin. Monitor well again. Hole is still stable. 14:00 - 14:55 0.92 FISH ClRC DECOMP Rig up to circulate. Mix and pump 15 bbl 14 ppg dry job. Displace with 3 bbls. RD circulating equipment. 14:55 - 21:05 6.17 FISH TRIP DECOMP Begin POOH with drill pipe and BHA. Good hole fill coming out. No drag seen. Pulling 100K off bottom. 112 stands of drill pipe removed and 321' BHA. Lost 9 bbls beyond pipe displacement. Retrieved part of fish, the slick stick, J-Latch Assy, 2' pup, & top sub of packer. The total length of fish 10.87'. This will put the top of the fish (packer) @ 7434' now. 21:05 - 22:00 0.92 FISH PULD DECOMP Lay down Fish and BHA. Monitor well and looks good no gains & no losses. Prepare for BOP test. 22:00 - 00:00 2.00 WELCTL BOPE DECOMP BOP Test in progress. Chuck Scheve waived witness of test. =9/21/2003 00:00 - 04:00 4.00 WELCTL BOPE DECOMP Finish BOP Test. Prep floor to pick up BHA. Well is still dead. 04:00- 05:30 1.50 FISH PULD DECOMP Pick up Fishing Spear BHA 05:30 - 08:00 2.50 FISH TRIP DECOMP Trip in the hole 3.5" drill pipe and BHA 08:00- 12:00 4.00 RIGMNT RSRV DECOMP Slip and cut drilling line. 12:00 - 13:00 1.00 FISH TRIP DECOMP Continue tripping in the hole with 3.5" drill pipe and BHA. 13:00 - 15:00 2.00 RIGMNT RSRV DECOMP Drilling line not spooling correctly on drum. Slip and cut drilling line again. Hold better tension while starting line on drum. Light blocks make spooling difficult. 15:00 - 17:00 2.00 FISH TRIP DECOMP Continue tripping in the hole with 3.5" drill pipe and BHA. 17:00 - 21:30 4.50 FISH CIRC DECOMP MU stand 112 and RIH. MU single w/head pin. MU two circulating hoses. Break circulation the long way. 133 spm at 1010 psi. Check weights. 102K up, 67K down. Line up to reverse circulate. Circulated 2+ surface to surface circulations for a total of 275 BBL @ 3 BPM & 920 psi. Mud weight in and out 12.2#. Monitored hole and it looked good. 21:30 - 21:40 0.17 FISH FISH DECOMP Lined up to pump down the drill pipe. Begin circulating @ 1.5 BPM & 500 psi. Check weights, 102K up and 67K down. Slowly lowered spear Printed: 10/17/2003 11:16:03 AM ConocOPhillips AlaSka Page 8 of 14 Operations Summa Report Legal Well Name: 2U-06 'Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Sub Phase DeScription of Operations Date From - To Hours COde Code 9/21/2003 ~21:30 - 21:40 0.17 FISH FISH DECOMP into fish. Circulation pressure increased to 700 psi as spear entered into fish. Pulled up to 135K, fish engaged. 21:40 - 22:10 0.50 FISH JAR DECOMP Set jars off @ 135K and pulled up to 200K. Fish dragging a little minimal movement. Started jarring up at 165K ( 6 hits), 180K (5 hits), 190K (5 hits), 200K (10 hits) Then straight pulled up to 225K. Made maybe 6". 22:10 - 22:20 0.17 FISH JAR DECOMP Beat down from 125K to 45K (15 hits). Started jarring up 200K (5 hits) fish moved up app: 2'. Straight pull up to 225K. 22:20 - 22:45 0.42 FISH JAR DECOMP Beat down again from 125K to 45K (5 hits). Jarred up 210K (5 hits) fish moved up the hole another 3'. Continued jarring up @ 210K (5 hits). Straight pull to 235K fish moved up 2'. Beat down again (5 hits). Jarred up 210K (15 hits) and straight pull up to 230K. Fish moved up hole a little on every hit. Worked up another 7' for a total of 14' 22:45 - 23:00 0.25 FISH JAR DECOMP Jarred up 210K (5 hits) with fish moving about 1' every hit. Straight pulled up to 230K and fish came free. Dragging up the hole pulling 122K about 20K over but jumping up and down. Pulled up 26' placing 1st stand tool joint just above the floor. 23:00 - 00:00 1.00 FISH CIRC DECOMP Started circulating down the drill pipe @ 2 BPM & 780 psi. Attempted to work fish down but unable to move down. Fish still moves up @ 110K. Continued circulating 9/22/2003 00:00 - 01:00 1.00 FISH CIRC DECOMP Continued circulating hole down the drill pipe 2 BPM & 780 psi. Completed 1+ surface-surface circulation 266 bbls. 01:00 - 01:30 0.50 FISH ClRC DECOMP Monitored hole for gains/losses. The hole is static prepared for trip. 01:30 - 01:55 0.42 FISH CIRC DECOMP Pump 14.2# 19 bbl dry job. Break out the head pin. 01:55 - 08:15 6.33 FISH TRIP DECOMP Start tripping pipe CCH. Weight off botttom 110K about 8K over. On surface hole displacement (6 BBL loss). Prepare to lay down fish. 08:15 - 11:30 3.25 FISH PULD DECOMP Pull fishing tools to rig floor. Otis RRH packer has 1 slip missing along with 2-1/4 elements. Flowrate jumped 21% with no visual increase in flow. Pull apart flow meter. Found ? piece of element. This does not match the ? piece recovered. Attempt to removed spear from packer. Lost 1 slip down the mousehole. Continue to pull fish out of hole. Pull and LD 1 jt 3.5" tubing and 1-MMG production mandrel. Pick up on tubing. Started taking weight. Drain stack. Pick up on pipe. Can see packer slip riding on next collar in tubinghead. Slip fell downhole when collar cleared the tubing head. Continue to pull. 11:30 - 12:15 0.75 FISH PULD DECOMP Slip came up to tubinghead on the next MMG production mandrel. Have HES hotshot for magnet. MU magnet on 1-1/2" stem. Run magnet through BOP stack. Pick up slip with magnet. Pull up through stack. Slip fell off and wedged beside production mandrel in tubinghead. Cannot move pipe down. Pull up to 10K over and pipe will not move. Rotate pipe to the right and slip fell downhole. Pull out with remainder of fish. Recovered 1-Otis RRH packer, 1 jt 3.5" J-55 tbg, 1-MMG production mandrel, 2 jts 3.5" J-55 tubing, 1-MMG production mandrel, and 1-16' 3.5" J-55 cut off joint. 12:15 - 12:30 0.25 WELCTL OBSV DECOMP Monitored hole for flow. Hole looks good continue on as planned. 12:30 - 14:00 1.50 FISH PULD DECOMP Clean up rig floor. Pull Recovered fish out of pipe shed. Checked out fish for NORM. Load wash pipe and fishing tools for next run. 14:00 - 18:00 4.00 FISH PULD DECOMP MU washover shoe, wash pipe, rolling dog overshot, wash pipe extension, bumpersub, jars, 5 4-3/4" drill collars, and accelerator. Had to PU 1 new drill collar and LD 5 drill collars out of the derrick. All drill collars on this trip have at least 2-1/4" ID. Smallest available chemical cutter is 2-1/8". 18:00 - 00:00 6.00 FISH TRIP DECOMP Trip in the hole with BHA on 3.5" drill pipe. Having to trip very slowly Printed: 10/17/2003 11:16:03 AM ConocOPhillips Alaska Page 9 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: 'Rig Name: Nabors 3S Rig Number: Date From'- To Hours Code Sub Phase Description of Operations Code 9/22/2003 18:00 - 00:00 6.00 FISH TRIP DECOMP because mud is wanting to push out the top of the drill pipe. Tight tolerance between 6" wash pipe and 7" casing. 80 stands plus BHA in the hole at midnight. Hole displacement looks good. 9/23/2003 00:00 - 03:35 3.58 FISH TRIP DECOMP Continued tripping in the hole slow. Bottom of BHA stopped at 7623'. Hole displacement showed gain of 6 bbls. MU head pin and prepare to :circulate. Hole is static. 03:35 - 05:35 2.00 FISH ClRC DECOMP Begin reverse circulating @ 3 BPM & 1400 psi. Circulating pressure dropped back to 870 psi by the time Bottoms up was coming up. Had some sand coming back in returns on initial bottoms up. Circulated 1+ surface-surface circulation and evened mud weight out 12.2# in and 12.2# out. 05:35 - 05:45 0.17 FISH WASH DECOMP Checked weight with bag closed and circulating 3 BPM. Up weight 110K and down weight 57K. 05:45 - 06:00 0.25 FISH WASH DECOMP Shut down the pump and opened the Bag, to get a dry tag. Dropped on down and tagged up @ 7628' 06:00 - 06:30 0.50 FISH WASH DECOMP Closed the bag again and fired off the pump to reverse circulate. Dropped on down stripping through the Bag and circulating 3BPM @ 870 psi. Washed down to 7640' 06:30 - 07:00 0.50 FISH WASH DECOMP Continued reversing but unable to make anymore hole. Looks like we are sitting on some of the lost packer elements. 07:00 - 08:00 1.00 FISH WASH DECOMP Picked up the Kelly to attempt to mill out rubber packer elements. 08:00 - 09:30 1.50 FISH MILL DECOMP Lined up to pump conventional 3 BPM @ 650 psi and Kelly in place start rotating @ 80 RPM and milling on rubber elements. Worked down to 7644' very slow going. Saw a little rubber bits and pieces come over the shakers. 09:30 - 12:30 3.00 FISH MILL DECOMP Continue milling pumping down tubing @ 3 bpm and rotating kelly @ 120 RPM. Fine metal returns with some small rubber pieces and small amounts of sand. Worked up and down with pipe and varied pump rate and 12:30 - 13:30 1.00 FISH ClRC DECOMP Shut down pump and pick up 10'. Start reverse circulating for a surface to surface (14500 strokes). Small amount of sand, rubber and metal filings. Stripped through bag and sat down @ 21' into kelly joint - joint #231 in the hole. No further progress downhole. 13:30 - 17:30 4.00 FISH MILL DECOMP Begin milling again with no progress. Slacked off 20k while milling and 30-35k while not rotating. Pumping 3 bpm down tubing and rotating up to 120 rpm. Attempted all running speeds, pump rates and rotational rpms. No progress and unable to get shoe to torque up while pumping. Some torque while not pumping. Acts like slip and rubbers are spinning downhole on top of the the tubing stub. 17:30- 19:00 1.50 FISH ClRC DECOMP Confered with engineering. Unable to make progress. Elected to reverse out again. Reversed a bottoms up (60 bbls) and attempted to strip through bag to tag fish again. Reversed out another bottoms up attempting to move rubber/slip into BHA or drillpipe. 19:00 - 20:00 1.00 WELCTL OBSV DECOMP Begin prepping to trip out of hole to check BHA and add another shoe. Monitor well, static. Pump slug. 20:00 - 00:00 4.00 FISH TRIP DECOMP Set Kelly back. POOH to inspect & change washover shoe. 9/24/2003 00:00- 02:00 2.00 FISH TRIP DECOMP Continue POOH with DP. 02:00- 04:30 2.50 FISH TRIP I DECOMP POOH with DCs and washover assembly. Checked rolling dog overshot, still in good condition. Found "cripple" shoe worn out. Shoe was worn smooth on bottom and about 9-1/2" of shoe wash worn and torn off, metal torn off was recovered up inside shoe. Also recovered two pieces of thin metal (approx. 0.130" thick) from inside shoe: one piece about 4" long, second about 7" long, both about half Printed: 10/17/2003 11:16:03 AM ConocoPhillips Alaska Page 10 of 14 Operations Summar Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 ;Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From -To Hours Code Sub Phase DescriPtion of Operations Code 9/24/2003 02:00 - 04:30 2.50 FISH TRIP DECOMP circumference of a 4-1/2" to 4-3/4" diameter, thin tube. Does NOT look like casing or tubing. Possibly pieces from SBR/Packer assembly fished from well. 04:30 - 06:00 1.50 FISH PULD DECOMP Make up new wash over shoe. Shoe is flat bottomed (4 water courses) with Cutrite on bottom, smooth on ID & OD. RIH with wash over pipe and rolling dog overshot fishing assembly. Rill with DC. 06:00 - 13:30 7.50 FISH TRIP DECOMP RIH with DP & washover shoe assb. Mix up a weighted pill to keep flluids from pouring over the drillpipe. Tagged fish @ 7744' and picked up 1'. Rigged up Kelly and set up to reverse out bottoms up. Fish @ 20' up Kelly joint with joint #231 in the hole. 13:30 - 14:30 1.00 FISH CIRC DECOMP Reverse out bottoms up @ 3 bpm for 80 bbls. until hole cleaned up. 14:30 - 22:30 8.00 FISH WASH DECOMP Begin milling on junk in hole to attempt to wash over the stub and blast rings. Made slow but continuous progress. 3000-5000k down weight pumping 2-3 bbl/min pump rates @ 600-700 psi. Picked up occasionally to assure pipe was free. Made 2.5 feet from dry tag at 1830 hrs. Top of stub at 7644', Nabors RKB. Continued washing over, 90-100 RPM, 120 SPM, 500-700 psi, 2K#-5K# on shoe. Making steady, slow progress to 7650'. Broke through at 7650'. 22:30 - 23:30 1.00 FISH WASH DECOMP Continued washing over and rotating down with little to no weight to 7665'. Circulate a few minutes. PU to top of stub and wash back down, OK. No drag. 23:30 - 00:00 0.50 FISH CIRC DECOMP Reverse circulate 2-1/2 DP volumes to clean hole. No significant returns over shaker, some fine sand/carbolite and a few bits of rubber. 9/25/2003 00:00 - 01:00 1.00 FISH CIRC DECOMP Continue reverse circulating 2-1/2 DP volumes to clean hole. No change in returns over shaker, small amount of fine sand/carbolite and a few bits of rubber. 01:00 - 02:30 1.50 FISH WASH DECOMP Make connection. Wash down without rotating, slip over stub OK, wash down to 7665'. No go washing deeper without rotating. Rotate and wash over fish to 7680'. PU & wash back down and had sudden partial loss of returns. Estimate loss rate at 35 BPH while circulating. 02:30 - 07:00 4.50 FISH ClRC DECOMP Stop circulating and monitor losses, filling hole on annulus side. 18 BPH initial static loss rate, slowed to 10 BPH while building LCM pill. Ordered additional mud for volume from MI mud plant. Mixed 30 Bbl LCM pill with 75 ppb of Safe-Carb (25 ppb each of Slug-It 500, Coarse 250, & Medium 40 Safe Carb). Spotted pill down DP, displaced to put 15 Bbls outside pipe, leaving 15 Bbls inside DP. Loss stopped as soon as pill was spotted. Will monitor hole and let C-Sand heal for about an hour before attempting to resume washing over. Working pipe to be sure it stays free. Pumped 1/2 bbl a couple times to be sure we maintain circulation. Estimated volume lost, 35 Bbls. 07:00 - 10:30 3.50 FISH WASH DECOMP Hole stopped losing fluids. Start washing over process again. Had to rotate to make any hole. Made 6' of hole to 7686', about 2' over blast rings and unable to make further hole. Slacked off 20K down, rotated up and down with various speeds, pumped from 1 to 3 bbl/min trying all combinations. One pull up with pipe was sticky with 40K overpull. Up weight off bottom~115K. Discussed with Engineering and decided to circulate the long way and pump a high vis pill to help circ out junk. 10:30 - 15:30 5.00 FISH CIRC DECOMP Pulled above the blast rings to circulate the long way at 3 bpm. Saw LCM pill and some sand but no parts and pieces. Pumped a high vis pill to help circulate out sand and junk. Sand and metal sliver returns. Circulated 2.5 surface to surface - sand heavy at times. Continued to get sand and metal slivers throughout the circulation. Rig down Kelly and prep to POOH. Printed: 10/17/2003 11:16:03 AM ConocoPhillips Alaska Page 11 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date ' From-To HoUrs COde Sub phaSe Description of Operations Code . 9/25/2003 15:30 - 18:00 2.50 FISH PULL DECOMP Begin to POOH w/fishing assembly. Monitoring well every 5 stands. Normal hole displacement. Normal weight pull on pipe. Well started flowing slowly out of drillpipe at shift change, 30 stands out. Fluid falling slowly in annulus. Appears to be slightly out of balance. 18:00 - 21:00 3.00 FISH ClRC DECOMP Install head pin & hose. Circulate well, getting 11.9 ppg mud out, 12.2 ppg in. Circulate mud around, weight up light mud and condition mud to balance out. Monitor well for 30 minutes, well static. 21:00- 00:00 3.00 FISH PULL DECOMP Pump 15 bbl slug. Continue POOH. 9/26/2003 00:00- 02:00 2.00 FISH PULL DECOMP Continue POOH to BHA. 02:00- 04:00 2.00 FISH PULL DECOMP POOH with BHA. Found 0.40' gone from bottom of wash-over shoe - cleanly cut off, like a lathe cut, from the inside to the outside. Cut indicates some broken carbide blast rings. Also some cuts about 4" to 6" inside shoe. 04:00- 04:30 0.50 RIGMNT RSRV DECOMP Service rig. 04:30- 07:30 3.00 FISH PULD DECOMP LD wash-over pipe. Clear rig floor. Monitor well, static. Prepare to PU dressing mill, boot baskets, and casing scraper to clean out hole and dress off tubing stub. 07:30 - 09:30 2.00 FISH PULD DECOMP PU dressing mill, 3 boot baskets, and 7" casing scraper to clean out hole and dress off 3-1/2" tubing stub. 09:30 - 16:00 6.50 FISH TRIP DECOMP RIH w! dressing and cleanout assembly w/triple dressing mill on bottom (total length BHA 207.98'). 16:00 - 17:00 1.00 FISH MILL DECOMP PU Kelly. Found stub at 16' up Kelly joint with 234 joints in the hole. Dry tagged, picked up rotated onto stub (130 RPM), tagged top and worked down 8'. Let drill off to polish stub. Picked up until full up weight, (slight overpull), back at 102k. 'Fop of stub at 7644', dressed outside of 3-1/2" stub 8' down from top to 7652', and dressed inside about 3" down from top (triple mill: inside, outside, and top). 17:00 - 19:30 2.50 WELCTL CIRC DECOMP Circulate well reversing up drillpipe. Watched hole closely for losses. Sand, Safe-Carb LCM, and small rubber chunks in returns. Reversed hole volume plus 2 bottoms up to clean hole. Loaded one row of J-55 tubing while reverse circulating (75 jts: 15 jts pipe from 2U-06, to rerun & 60 its Tuboscope inspected used pipe). Tubing drifted to 2.85", but would not drift with 2.91" rabbit. 19:30 - 20:30 1.00 WELCTL OBSV DECOMP Monitor well 15 minutes, static. Pump slug. Set kelly back in rat hole. 20:30 - 23:15 2.75 FISH PULD DECOMP POOH - LDDP. 60 joints laid down, 1 row in shed. 23:15 - 00:00 0.75 FISH PULD DECOMP Re-Strap drill pipe & tally same. Remove DP from shed. Note: Re-strapping drill pipe at request of engineering. 9/27/2003 00:00 - 01:00 1.00 FISH PULD DECOMP Finish strapping 60 its of DP laid down. Remove from shed. 01:00 - 03:00 2.00 FISH PULD DECOMP RD drill pipe tongs & spinner. RU 'DD' tongs. PU Kelly and make service breaks, so it can be laid down at end of trip. RD big tongs. RU drill pipe tongs & spinner. RU air slips & stripping rubber. 03:00 - 05:15 2.25 FISH PULD DECOMP Continue POOH - LDDP. 120 joints out. 05:15 - 06:30 1.25 FISH PULD DECOMP Strap additional 60 jts of DP laid down. Unload from shed. 06:30- 12:00 5.50 FISH PULD DECOMP Continue POOH - LDDP. 12:00 - 13:00 1.00 FISH PULD DECOMP Continue to POOH-LDDP. Pumped one dry pill. 13:00- 13:30 0.50 FISH PULD DECOMP At the BHA. STBY for lunch break. Prep to pull BHA. Inspect and meet with CPF 2 & 1 over rig moving issues. 13:30 - 15:15 1.75 FISH PULD DECOMP Begin pulling BHA and layed down. Dressing mill shows definite wear and appeared to be properly over stub. i 15:15 ~ 16:00 0.75 CMPL'FN PULD CMPL'FN Strap pipe & empty pipe shed of drllpipe and BHA. PU tubing and load I pipe shed for completion. J~55 tubing is used from this and other wells. 16:00 - 00:00 8.00 CMPLTN PULD CMPLTN PJSM on laying down Kelly and swivel. Continue loading J-55 tubing pulled from this well, to be re-run. Drift, strap, & tally same. Drain oil Printed: 10/17/2003 11:16:03 AM ConocoPhillips Alaska Page 12 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: .Rig Name: Nabors 3S Rig Number: Date Erom- To HOurs Code Sub Phase Description of Operations Code 9/27/2003 16:00 - 00:00 8.00 CMPLTN PULD CMPLTN from swivel & lay down. Remove Kelly hose & rat hole. RD 3-1/2" DP handling tools. RU 3-1/2" tubing tools. 9/28/2003 00:00 - 01:00 1.00 CMPLTN PULD CMPLTN Finish drift, strap & tally used J-55 tubing to be re-run. Bring in 17 joints of inspected L-80 used tubing, drift to 2.91", strap & tally for use above 2.875" DS-Nipple at approx. 500'. Bring in jewelry, drift, strap & tally same. 01:00 - 01:30 0.50 CMPLTN SFTY CMPLTN PJSM on running 3-1/2" completion. 01:30 - 06:00 4.50 CMPLTN RUNT CMPLTN MU Baker Poor Boy overshot & pup on joint of slotted tubing. Run 2 jts tbg, 2.75" D-Nipple w/RHC on 10' pups, 2 jts tbg, Baker PBR / FHL Packer assy, 1 jt tbg, 'MMG' GLM w/shear valve on 10' pups. Continue running tubing and 'MMG' GLM's w/DV's. 80 joints run at 0600 hrs. 06:00 - 14:30 8.50 CMPLTN RUNT CMPLTN Continue to RIH w/completion. Sat down 52' high (3 foot into joint 265, tally number - 237th joint run) @ about 7592'. 14:30- 17:30 3.00 CMPLTN ClRC CMPLTN Circulate down tbg and up casing. Circulation established @ 2.5 bpm and 700 psi max pressure. Unable to make hole. Switch to reverse out. Did a surface to surface plus 100 bbls getting heavy sand/bar combo returns. Hole finally cleaned up. Opened bag and monitored hole. Dry tagged and sat down 15K at the same spot @ 7592'. Reverse out didn't clean below overshot because of slotted liner. Rig up to pump the long way to balance hole - mud weight unbalanced due to previous dry jobs. 17:30 - 20:30 3.00 CMPLTI~ CIRC CMPLTN Circulate to condition and balance out mud, 2.5 BPM, 450 psi. Re-tag fill at same spot, 9592'. 68K# Up Wt, 40K# Dn Wt. Pump slug. 20:30 - 00:00 3.50 CMPLTI~ TRIP CMPLTN POOH standing back tubing, SLM. 75 stands out at 2400 hrs. Plan to replace slotted joint of tubing with a Baker CMU Sliding Sleeve (in closed position) to allow circulation at bottom to wash over the stub with the poor boy overshot. 9/29/2003 00:00 - 04:00 4.00 CMPLTE TRIP CMPLTN POOH standing back tubing & GLM's, SLM. LD Baker PBR / FHL Packer assembly - looks new, shear ring in starting position, PBR pins OK. LD 2.75" D-Nipple (w/RHC) assembly, eyeball - OK. LD slotted joint and XO's, to be replaced with Sliding Sleeve. LD Baker Poor Boy overshot. O/S was clear, had a bit of fine solids in guide, probably barite. No new scratches or scars in guide..SLM 2' short, OK, no change. 04:00 - 13:00 9.00 CMPLTN RUNT CMPLTN MU Baker poor boy overshot and pup on Baker 2.812" CMU Sliding Sleeve (in closed position) assembly, 6' pups top and bottom. Run 1st stand tbg. MU 2.75" D-Nipple (w/RHC) assembly, 10' pups top & bottom. Run 2nd stand tbg. MU Baker PBR / FHL Packer assembly, 6' pups top & bottom. RBIH with 3-1/2" completion string from derrick. 13:00 - 19:30 6.50 CMPLTN CIRC CMPLTN Start reverse out - sat down at the same depth as yesterday 7593'. Worked pump up to 3.5 bpm. Unloaded heavy sand and heavy mud @ 14.5#. Able to stick overshot with 20K overpull but unable to make hole. Continue to reverse out at different pump speeds with sand tailing off. 1 cu/yd of sand/barite combination total. Discussed with Engineering. Indexed pipe two turns at a time working torque down to bottom with reverse out after indexing through closed bag. Still unable to make hole. 8 turns total indexing. Continue to reverse out attempting to make hole while waiting on orders. 2.5 BPM, 550 psi. Sitting down at the same depth every cycle. 72K# PU, 42K# SO. 19:30 - 20:00 0.50 CMPLTN OBSV :CMPLTN Monitor well, static. Pump slug. 20:00 - 00:00 4.00 CMPLTN TRIP CMPLTN ' POOH standing back tubing. LD GLM's and other jewelry. 90 stands out at 2400 hrs. 9/30/2003 00:00 - 02:45 2.75 CMPLTN TRIP CMPLTN i Finish POOH, stand back tubing, LD jewelry. Baker PBR/FHL Packer Printed: 10/17/2003 11:16:03 AM ConocoPhillips Alaska Page 13 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From-To HoUrs Code Sub Phase Description of Operations Code 9/30/2003 00:00 - 02:45 2.75 CMPLT~ TRIP CMPLTN assembly in good shape, plan to send it in to have it checked out. Guide on poor boy overshot clean and has no new marks. 02:45 - 09:30 6.75 WELCTL BOPE CMPLTN Clear floor. RU to test. Set test plug. Test BOPE. Started BOP test at 0430 and completed at 0930. Tested blinds, pipe rams, and choke manifold to 250 psi & 4000 psi; Annular to 250 psi & 3500 psi. Witnessing of weekly test waived by John Crisp, AOGCC Field Inspector. Start loading and strapping drillpipe in shed during test. 09:30- 15:00 5.50 FISH PULD CMPLTN Continue loading and strapping drillpipe. 15:00 - 17:00 2.00 FISH PULD CMPLTN PU BHA with original dressing mill, 2 boot baskets, 7" casing scraper, bumper sub, oil jar, and 9 - 4-3/4" drill collars. 17:00 - 00:00 7.00 FISH PULD CMPLTN RIH with dressing mill and cleanout assembly, picking up drill pipe. 130 joints picked up at 2400 hrs. 10/1/2003 00:00- 05:30 5.50 FISH PULD CMPLTN Continue RIH with dressing mill and cleanout assembly, picking up drill pipe. RIH to 7563'. ,05:30 - 09:00 3.50 FISH ClRC CMPLTN MU head pin & hose. Circulate to water mud back to 12.2 ppg and condition mud system, prior to cleaning out well. 09:00 - 11:30 2.50 FISH WASH CMPLTN Lowered dressing mill on DP down to 34" below where suspected fill (7592') to 7626'. Did not see anything at this point. Circulated bottoms up with no recordable sand. Made another connection went down to top of stub went over did not see top of stub. Went down to 7652' started pumping down to 7655'. Pulled back off of stub but could not get back over stub with pumps on. Finished pumping bottoms up. Shut down pumps and went right over stub down to 7655' with no problems. This is 11' over top of stub. 11:30 - 14:00 2.50 FISH CIRC CMPLTN Circulated 2 hole volumes to clean up. Pumped high vis pill and spot on bottom. 14:00 - 16:00 2.00 FISH TRIP CMPLTN POOH, wet, LD 25 joints of DP. Pump slug. 16:00 - 21:00 5.00 FISH TRIP CMPLTN POOH standing back DP, 103 stands. 21:00 - 23:00 2.00 FISH PULD CMPLTN POOH LD drill collars, and clean out BHA. Recovered one small piece of metal (1/4" x 1-1/2" x 1 ") wedged in water course just inside shoe. No junk in boot baskets. 23:00 - 00:00 1.00 FISH PULD CMPLTN Clear off and clean rig floor. Load out clean out tools. 10/2/2003 00:00- 00:30 0.50 RIGMNT RSRV CMPLTN Service rig. 00:30 - 02:30 2.00 CMPLTN PULD CMPLTN Load shed with modified poor boy overshot assembly, sliding sleeve assy, D-Nipple assy w/RHC, and new PBR / FHL Packer assy. Strap & caliper same. RD drill pipe spinners. RU tubing tongs. RU tools to run tubing. 02:30 - 04:00 1.50 CMPLTN PULD CMPLTN PJSM on running Packer and tail on DP, rig floor crowded with tubing & DP in derrick. PU Poor Boy overshot assembly (Muleshoed 5-3/4" x 5" WP extension, 4' long + 1' XO + 3-3/4" ID O/S barrel, 5' long + 6' pup). RIH on 1 stand of 3-1/2" tubing. PU & MU Baker CMU Sliding Sleeve w/2.750" D-profile and 6' pups top and bottom. RIH on 1 stand of tubing (Stand #2). PU & MU 2.812" DS-Nipple with RHC in place and 8' pups top and bottom. RIH on 1 stand of tubing (Stand #3). PU & MU new Baker PBR / FHL Packer assy with 6' pups top and bottom. 04:00- 04:30 0.50 CMPLTI~ TRIP CMPLTN RD tubing tongs. RU DP spinners. RU tools to run DP. MU crossovers from tubing to drill pipe. 04:30 - 09:00 4.50 CMPLTI~ TRIP CMPLTN Run Packer and Tailpipe assembly in hole on DP. Mud running over, pumped dry job. 09:00 - 12:00 3.00 CMPLTI~ PCKR CMPLTN Rig up head pin to circulate. At jt 233 up wt 102K dwn wt. 65k. Tagged top of stub at 7644'. Picked up 2' reversed one hole volume to clean up. Lowered overshot and stacked out but did not get a press increase. Printed: 10/17/2003 11:16:03 AM ConocoPhillips Alaska page 14 of 14 Operations Summary Report Legal Well Name: 2U-06 Common Well Name: 2U-06 Spud Date: 3/7/1985 Event Name: WORKOVER/RECOMP Start: 9/10/2003 End: Contractor Name: Nabors3SCompM@conocophilli Rig Release: Group: I Rig Name: Nabors 3S Rig Number: Date From-To Hours Code Sub Phase Description of Operations Code 10/2/2003 12:00 - 16:30 4.50 CMPLT~ PCKR CMPLTN Dropped I 7/16" setting ball on rod waited 15 min. for ball to fall. Ball on seat pressured drill pipe to 2500 psi held for 15 min. (charted). Bleed pressure to 1500 psi. Picked up and sheared out of PBR @ 110K up wt. Pulled seals and test pkr and casing to 2000 psi for 15 rain with no bleed off (charted). Bleed off press. Est. circulation I BPM 200 psi. Stabbed into PBR press increased to 650 psi. 16:30 - 00:00 7.50 CMPLTN TRIP CMPLTN Pull and lay down drill pipe. 120 joints laid down @ 2400 hrs. 10/3/2003 00:00 - 03:30 3.50 CMPLTN TRIP CMPLTN Continue POOH LDDP. 180 joints laid down. 53 joints plus XOs, 3-1/2" pup & Baker seal assembly still in hole. 03:30- 05:30 2.00 WELLSR PLGM CMPLTN PU Baker storm packer. MU onto string. RIH and set storm packer at 30' below rig floor, about 6' below ground level. Test packer to 1000 psi for 5 minutes, OK. 05:30-16:00 10.50 WELLSRNUND CMPLTN Pump mud out of stack. ND choke & kill lines. ND BOP stack. ND McEvoy tubing head. Replaced 7" packoffs. Energized seals. Test packoffs to 3000 psi.. NU redressed tubing spool and BOPs. Set test plug, body test BOPs 250 psi & 4000 psi. Pull test plug. Pulled Baker storm packer. 16:00 - 20:00 4.00 CMPLTN TRIP CMPLTN POOH with remaining 53 jts drill pipe. LD crossovers. Baker seal assembly in good shape. 20:00 - 22:00 2.00 CMPLTN RURD CMPLTN RD drill pipe spinners. Clear rig floor of DP handling equipment and crossovers. Clean rig floor. Unload DP from pipe shed. 22:00 - 23:00 1.00 CMPLTN RURD CMPLTN Load 1 joint of J-55 re-run tubing, 5 Gas Lift Mandrel assemblies, and 2 ioints of inspected L-80 tubing into pipe shed. Bring in & RU power tongs. RU to run 3-1/2" tubing. 23:00 - 00:00 1.00 CMPLTN RUNT CMPLTN MU 1 joint of J-55 tubing on top of Baker seal assembly. MU MMG gas lift mandrel (with 2000 psi annular shear valve) on top of joint. RIH with tubing in stands from derrick, installing GLMs as planned. Stand #13 RIH at 2400 hrs. (Note: First 3 stands are already in the hole, below the FHL packer. Top of PBR @ 7387'.) 10/4/2003 00:00 - 06:00 6.00 CMPLTI~ RUNT CMPLTN Run 3-1/2" completion, stands from derrick. PU GLMs as planned. 06:00 - 06:30 0.50 CMPLTI'q SEQT CMPLTN Circulate down looking for press, increase as seals enter PBR. Top of PBR @ 7386'. 06:30 - 08:00 1.50 CMPLTI'q RUNT CMPLTN Space out 3.5" tubing seals, pressure holding @ 230 psi. 08:00 - 10:00 2.00 CMPLTI~ CIRC CMPLTN Hole out of balance. Circulate and condition mud to 12.2 all around. 10:00 - 12:30 2.50 CMPLTI~ SOHO CMPLTN Spaced out with 26' of pups and tubing hanger. 12:30- 13:00 0.50 CMPLTI~ RUNT CMPLTN Drain BOPs land tubing hanger. RILDS 13:00 - 14:30 1.50 CMPLTI~ DEQT CMPLTN Press up 3.5" tubing to 2000 psi and monitored on chart for 15 rain with annulus open (no returns). Bled down tubing to 1500 psi. Press up annulus to 2000 psi monitored on chart 15 min. held OK. Bled press off tubing to zero to shear SOV in bottom GLM, (no shear). Press up annulus to 2400 psi and sheared valve. 14:30 - 15:30 1.00 CMPLTI~ RURD CMPLTN Lay down landing jt. Blow down lines, choke, pump. Pick up tee bar & install two way check valve. 15:30 - 20:00 4.50 CMPLTI~ NUND CMPLTN ND BOP & flow riser, turnbuckles, disconnect koomey lines. 20:00 - 23:15 3.25 CMPLTI~ NUND CMPLTN NU redressed McEvoy tubing head adapter & tree. Test adapter & seals to 5000 psi. Test tree to 250 psi & 5000 psi. Start cleaning pits while working on tree. 23:15 - 00:00 0.75 WELLSF RURD CMPLTN Clean up cellar area. Continue cleaning pits, lots of barite settled in corners and around suction lines away from agitators. 10/5/2003 00:00 - 02:00 2.00 WELLSF RURD CMPLTN Continue cleaning out barite settled out in pits. Vac truck picked up fluids from burms and sumps, also helping super sucker cleaning pits. 02:00- 04:00 2.00 WELLSF RURD CMPLTN Remove flowline. Prepare rig floor and derrick. Finish cleaning pits. Release Rig. Printed: 10/17/2003 11:16:03 AM Blast Ring (7677-7768, 0D:4.500) Peff (7851-7914) ConocoPhillips Alaska, Inc. 2U-06 APl: 500292128200 SSSV NIPPLE Annular Fluid: Well PROD 3/14/1985 Last W/O: 10/6/2003 Reference Last 7828 8/31/2003 - CASINGS -rD: 8286 ftKB Max Hole Anc CONDUCTOR Size 16.000 Top 0 Bottom 105 KRU TVD 105 SURFACE 9.625 0 3642 2979 PRODUCTION 7.000 0 8214 6104 Bottom TVD 7816 5835 Zone C-4,UNIT B A-4 A-3 A-2 TUBING Size Top 3.500 0 PerforatiOns Summary Interval TVD 7700 - 7754 5754 - 5792 7851 - 7866 5859 - 5869 7866 - 7914 5869 - 5902 7980 - 8007 5947 - 5965 2U-06 Rev Reason: WORKOVER, 10/31/2003 Gas Lift Mahdrels/Valves . · ,,. Man Type Iwt IGrade I 62.50I H-40 I 36.00 I J-55I 26.00 I J-55 I MMG MMG MMG MMG MMG Man Type Thread NIP IWt IGrade I 9.30 I J-55 I MMG-2 ,':JEWELRY '.' Thread EUE 8RD Comment BAKER POOR BOY OVERSHOT set 10/6/2003 - SWALLOWS 8' OF TUBING STUB OF ORIGINAL COMPLETION Description TBG CUT TBG CUT 8/31/2003 TBG CUT TBG CUT 8/31/2003 Locator PKR Otis 'WD' NIP Camco 'D' Nipple NO GO SOS Otis WLEG WlRELINE GUIDE Description Comment 1 1/2" DV Downhole 3 - 1 1/2" CV's 3 CV's in Rathole NIP CAMCO NO GO NIPPLE ~) GO PROFILE set 10/6/2003 SLEEVE-O BAKER CMU set 10/6/03, OPENED 10/30/2003 PACKER BAKER FHL RETRIEVABLE PACKER set 10/6/2003 PBR BAKER 80/40 PBR set 10/6/2003 CAMCO 'DS' NIPPLE set 10/6/2003 Description DA 5" DA 4" DA 4" MEMORANDUM TO: Julie Huesser, CommisSioner · THRU' Tom Maunder, P. I. Supervisor. .State of Alaska Alaska Oil and Gas Conservation Commission DATE' December 2, 2000 FROM' Chuck Scheve; Petroleum InspeCtor saturday~ DeCember 2, 2000: I travele¢ SUBJECT: Safety Valve Tests Kuparuk River Unit 2U Pad to the Kuparuk River Field and witnessed the semi annual safety valVe system testing on 2U Pad. As the attaChed ^OGCC Safety-Valve System Test Report indicates I witnessed the testing of 11 Wells and'22 components with three failures observed. The Iow · pressure pilots on wells 2U-5, 2U-14 and 2U-16 tripped well below the required set point. These three pilots Were adjuSted and retested at the time of this test. In addition to the three failed pilots several other pilots tripped very near the minimum pressure, these were reset and operated, prOperly when retested. The 13;6% failure-rate will require a retest of this Pads System in 90 rather than the nOrmal ,,~0._..day cyCle. Safety Valve days Earnie Barndt cOnducted the. testing today he demonstrated good test procedure and was a pleasure to work with SummarY:· I witnessed the semi annUal SVS testing at 2U Pad in the Kuparuk River Field. KRU 2U Pad, 11 welIs, 22 components, 3 failures 13.6% failure rate Attachment: SVS KRU 2U Pad 12-2-00 CS "X Unclassified , Confidential (Unclassified if doc. Removed) SVS KRU 2U Pad 12-2-00 CS.doc Operator: Phillips Operator Rep: Ernie Barndt AOGCC Rep: Chuck Scheve · Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2U Pad Separator psi: LPS 96 . HPS 12/2/00 Well Permit Separ Set L/P Test ' Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLe. 2U-01 1850040 96 70 .50 P P OIL 2U-02 1850050 96 . 70! 60 P P OIL 2U-03 185.0060 2U-04 1850070! 2U-05 18501-80 3700 ' 2000 500 3 P 12/2/00 WAG 2U-06 1850190 96 70 '50' P P OIL 2U-07A 1850910 2U-08 1850210 96 70 .50 P P OIL 2U-09 1850380 2U-10 1850390 96 70 60 P 'P- OIL 2U,11 1850400 . 2U-12 1850410 96 70 55 P P OIL 2U-13 1842460 -196 70 - 50 P P OIL 2U-14 ' 1842470 3700 2000 0 1 P 12/2/00 WAG 2U-15 1842480 96 ' 70 ,60 P P OIL 2U-16 · 1842490 3700 2000 100 3 P 12/2/00 WAG Wells: ' 11 Components:. 22 Failures: 3 Failure Rate: 13.6%E390 Day Remarks: Three failed pilots repaired and retested Pad on 90 day test cycle 1 9/4/013 Pa~e 1 of 1 SVS KRU 2U Pad 12-2-00 CS.xls :' " STATE OF ALASKA AL, ._.,:A OIL AND GAS CONSERVATION COMMb,,..,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 546' FSL, 718' FWL, Sec. 32, T12N, R9E, UM At top of productive interval 1517' FSL, 1053' FEL, Sec. 6, T11N, R9E, UM At effective depth 1234' FSL, 1191' FEL, Sec. 6, T11N, R9E, UM At total depth 1132' FSL, 1244' FEL, Sec. 6, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8286 6151 6. Datum elevation (DF or KB) RKB 106 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2U-06 9. Permit number/approval number 85-19 10. APl number 50-029-21282-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet Effective depth: measured 8 1 3 2 true vertical 6048 feet feet Junk (measured) 4 CV's in rathole Casing Length Structural Conductor 8 0' Surface 3 6 01 ' Intermediate Production 8178' Liner Perforation depth: measured 7700'-7754', true vertical 5753'-5791 ', Size Cemented Measured depth True vertical depth 1 6" 215 Sx CS II 105' 105' 9-5/8" 730 Sx PF E & 3642' 3020' 880 Sx PFC 7" 375 Sx Class G & 8214' 6103' 250 Sx PFC 7850'-7860', 5857'-5864', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7810' Packers and SSSV (type and measured depth) 7866'-7906', 5868'-5896', 7980'-8007' 5946'-5964' ORIGINA Packers: Otis RRH @ 7521' & Otis WD @ 7787'; SSSV: Camco TRDP-1A-SSA @ 1792' (Locked out) 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 10/2/97. Intervals treated (measured) 7850'-7860', 7866'-7906', 7980'-8007' Treatment description including volumes used and final pressure Pumped 146 Mlbs of 20/40 and 12/18 ceramic proppant into the formation, fp was 7123 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 6 7 539 1377 1316 192 Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 676 I 0 8 6 2045 1329 221 I16. Status of well classification as: Oil X Gas Suspended Service 17. Form 1/0z~0 ~ ,/ I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent P Date SUBMIT IN DUPLI~CATE uo.s Cons. Commission ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ '' WELL SERVICE REPORT ~ , K1 (2U-06(W4-6)) WELL JOB SCOPE JOB NUMBER 2U-06 FRAC, FRAC SUPPORT 0922971741.4 DATE DAILY WORK UNIT NUMBER 10/02/97 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 4 (~) Yes O NoI O Yes (~) No DS-YOKUM JOHNS -- ESTIMATE KD1577 230DS28UL $1 22,800 $145,237 Initial Tb.cl Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final t~ter Ann ' 1440 PSI 1300 PSI 1000 PSI 500 PSII 1250 PSI 400 PSI DALLY SUMMARY IPUMPED ''A'' SANDS REFRAC WITH 146'000# PROPPANT IN PERFS AND 20309# IN PIPE' WELL SCREENED OUT EARLY wHILEPUMPING 10 PPA 12/18 PROPPANT. I TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LI~-I'LE RED PUMP AND APC VAC TRUCK. 08:00 HELD SAFETY MEETING 08:48 PRESSURE TEST TREATING LINE TO 10144 PSI. 08:52 PUMP BREAKDOWN, 115 BBLS ,25 BPM; 7123 PSI TO 5259 PSI. 08:56 PUMP 1 AND 2 PPA SCOUR STAGES wiTH 5871# OF 20/40 PROPPANT AND FLUSH , SHUT DOWN FOR !.!3!P. i693 PSI. 10:53 PUMP DATA FRAC AND FLUSH 5 TO 15 BPM AND 5003 PSI.SHUT DOWN FOR ISIP 2092 PSI AND CLOSURE CALCULATION. 12:00 PUMP 440 BBLS OF PAD, 15 BPM AND 4568 PSI. 12:37 PUMP 2 PPA STAGE OF 20/40 PROPPANT 15439 #, 15 BPM AND 4532 PSI. 12:50 PUMP IN RAMP UP FROM 2 PPATO 10 PPA, 12/18,143809#, 15 BPM AND SCREENED OUT WITH 7123 PSI MAX PRESSURE, SHUTDOWN AND RDMO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $714.00 APC $7,400.00 $8,400.00 ARCO $400.00 $900.00 DOWELL $113,400.00 $118,200.00 HALLI BU RTO N $ 0.00 $8,604.00 LI'I-rLE RED $1,600.00 $8,420.00 TOTAL FIELD ESTIMATE $122,800,00 $145,238,00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 546' FSL, 718' FWL, Sec. 32, T12N, R9E, UM At top of productive interval 1517' FSL, 1053' FEL, Sec. 6, T11N, At effective depth 1234' FSL, 1191' FEL, Sec. 6, T11N, At total depth 1132' FSL, 1244' FEL, Sec. 6, T11N, R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 106 7. Unit or Property name Kuparuk River Unit 8. Well number 2U-06 9. Permit numbedapproval number 85-19 10. APl number 50-029-21282-00 11. Field/Pool R9E, UM 8286 feet 61 51 feet Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 81 3 2 true vertical 6048 feet feet Junk (measured) 4 CV's in rathole Casing Length Structural Conductor 8 0' Surface 3 6 01 ' Intermediate Production 8178' Liner Perforation depth: measured 7700'-7754', true vertical 5753'-5791', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7810' Packers and SSSV (type and measured depth) Size Cemented I 6" 215 Sx CS II 9-5/8" 730 Sx PF E & 880 Sx PFC 7" 375 Sx Class G & 250 Sx PFC 7850'-7860', 7866'-7906', 5857'-5864', 5868'-5896', Measured depth True vertical depth 105' 105' 3642' 3020' 8214' 7980'-8007' 5946'-5964' 6103' .. Packers: Otis RRH @ 7521' & Otis WD @ 7787'; SSSV: Camco TRDP-1A-SSA @ 1792' (Locked out) 13.IntervalsStimulati°ntreated°r cement(measured)Squeeze summary ~ ~~"1 I~.,'~ ~ L '~t' ~ II ~' ~ '1~ i'" Acid stimulate 'C' Sands on' 2/2/97. _ ! ," 77OO'-7754' Treatment description including volumes used and final pressure Pumped 106 bbls of 12% HCL & 43 bbls 13.5%/1.5% HF Mud Acid, fp was 1100 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation I 7 5 874 377 1300 Subsequent to operation ORIGINAL Tubing Pressure 225 284 436 1326 1316 203 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 1.0..:4~4 R~'~/88 Title Wells Superintendent SUBMIT IN DUPLICATE ARCO AlaSka, Inc. KUPARUK RIVER UNIT ---- WELL SERVICE REPORT '~ K1(2U-06(W4-6)) WELL JOB SCOPE JOB NUMBER 2U-06 ACID STIM, ACID SUPPORT 1013961759.1 DATE DAILY WORK UNIT NUMBER 02/02/97 "C" SAND ACID TREATMENT & FLOWBACK DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 7 (~) Yes O NoI (~) Yes C) No DS-JOST CHANEY FIELD AFC_,~ CC# DAILY COST ACCUM COST Sidled' ESTIMATE KAWWRK 230DS28UL $38,574 $74,133 .,,' Initial Tb_q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer/Adn 1880 PSI 1 100 PSI 1530 PSI 1800 PSII 200 PSII //200 PSI DALLY SUMMARY ''C'' SAND ACID TREATMENT COMPLETED' INJECTED 106 BBLS OF 12% HCL & 43 BBLS OF 13'5%/1'5% HF MUD ACID' THENFLUSHED W/DIESEL. ACID FLOWBACK IN PROGRESS.. I : TIME LOG ENTRY 07:00 MIRU DOWELL PUMPER, APC DIESEL TANKER, AND APC VAC TRK. HELD SAFETY MEETING (7 ON LOCATION/. 09:30 PT'D LINES TO 3000 PSI. 10:00 PUMP 10 BBLS OF DIESEL, RATE @ 1 BPM, WHTP 1850 PSI, 7" CSG PRESSURE 1530 PSI. 10:10 PUMP 63 BBLS OF 12% HCL, RATE @ 3 BPM, WHTP 1150 PSI, 7" CSG PRESSURE 1690 PSI. INCREASE IN 7" CSG PRESSURE DUE TO TEMP OF TREAMENT FLUIDS. 10:37 10:55 11:11 11:50 12:00 13:00 16:00 PUMP 43 BBLS OF 13.5% HCL/1.5% HF MUD ACID, RATE @ 2 TO 3 BPM, WHTP 1480 PSI, 7' CSG PRESSURE 1820 PSI.INCREASE IN 7" CSG PRESSURE DUE TO TEMP OF TREAMENT FLUIDS. WHEN ACID HIT THE PERF'S WHTP INCREASED AND HAD TO REDUCE PUMP RATE AS PUMPING CONTINUED ACID CLEANED UP SLUDGE @ PERF'S AND WHTP LOWERED. PUMP 43 BBLS OF 12% HCL, RATE @ 3 BPM, WHTP 1440 PSI, 7" CSG PRESSURE 1920 PSI. INCREASE IN 7" CSG PRESSURE DUE TO TEMP OF TREAMENT FLUIDS. PUMP 76 BBLS OF DIESEL, RATE @ 2.5 BPM, WHTP 1500 PSI, 7" CSG PRESSURE 1950 PSI. INCREASE IN 7" CSG PRESSURE DUE TO TEMP OF TREAMENT FLUIDS. JOB COMPLETE. SHOT FLUID LEVEL ON THE 7" CSG, APPEARS TO BE OK PER ENG. MONITORED WHTP FOR 15MINS. SITP WAS 1400 PSI @ 5 MINS, 12OO PSI @ 10 MINS, AND 1100 PSI @ 15 MINS. STARTED RD OF DOWELL EQUIP. RDMO DOWELL & APC TANKER AND vAc TRK. PREPPED TO BEGIN THE FLOWBACK. STARTED FLOWBACK, FLOW STABILIZED AND KICKED OFF L/G. FLOWBACK IN PROGRESS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,701.00 APC $8,250.00 $11,250.00 BAKER OILTOOLS ;-%'i ~i~'~;~ .~ ...- ~ r~. i- ? - ~ ~ .;. ~ i, -"-i ~-'- $0.00 $1,310.00 DIESEL ~ ¢ ~-J i ~ --' '~--¢~-' ~ '-~ $375.00 $681.00 DOWELL $21,949.00 $29,269.00 HALLIBURTON $0.00 $13,007.00 LI'I-I'LE RED $0.00 $8,915.00 PTS $8,000.00 $8,000.00 TOTAL FIELD ESTIMATE $38,574,00 $74,133,00 ARCO Alaska, Inc. Date: September 20, 1991 Transmittal #: 8227 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. Receipt Drilling Cement Bond Log Cement Evaluation Log ,.~Cement Bond Log ~:~ement Evaluation Log ~A~lavPac Log _ avF'ac Log ,,,Gamma Collar Log .,.-Cement Evaluation Log Cement Bond Log 9-8-91 9-8-91 9-11-91 9-11-91 8-26-91 7-20-91 7-20-91 9-12-91 9-12-91 .,Cement Bond Log 13 I" ~' ~- ~ ~ 1,..4,;.9 1 ,,-Cement Evaluation Log., I~. E ~ I~ ! ~ ~ 1 - ~_- ~S~./~9 ,9~Date Acknowledge: ~~~_-_~- Da' · ~x.~." _Alas~a~O.',~.~. Ga~ Cons. Cgmmission ~ State of Alaa~~p~a) 10382-12250 10382-12250 6705-7558 6705-7550 6400-6700 7810-8000 7810-8000 8678-9968 8678-9968 6705-7556 6705-7558 ARCO Alaska, In,,' Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal # 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-4 Dual-Zone PBU ~A'-Sand 7-14-87 2Z-4 Dual-Zone PBU 'C' Sand 7-14-87 2Z-12 Dual-Zone PBU 'C' Sand 7-2-87 2Z-12 Dual-Zone PBU 'A' Sand 7-2-87 2U-15 Pressure Buildup 5-28-87 2W-6 Dual-Zone PBU 'C' Sand 7-15-87 2W-6 Dual-Zone PBU 'A"Sand 7-15-87 3M-9 Static Well Pressure Report 7-26-87 3M-3 Static Well Pressure Report 7-17-87 3M-8 Static Well Pressure Report 7-28-87 2Z-6 Static Well Pressure Report 7-21-87 2Z-8 Static Well Pressure Report 7-25-87 2U-6 Static Well Pressure Report 7-19-87 3I-9 BHP Report 7-16-87 2W-7 Static Well Pressure Report 7-21-87 2X-lO Static Well Pressure Report 7-17-87 2X-14 Static Well Pressure Report 7-17-87 2X-12 Static Well Pressure Report 7-17-87 2W-3 Pressure.Buildup Test 7-4-87 2Z-2 Static Well Pressure Report 7-17-87 2Z-6 Static Well Pressure Report 7-13-87 2Z-2 Static Well Pressure Report 7-9-87 2Z-8 Static Well Pressure Report 7-13-87 3M-1 Static Well Pressure Report 7-13-87 3M-2 Static Well Pressure Report 7-13-87 1Y-lO Static Well Pressure Report 4-23-87 1Y-4 Static Well Pressure Report 4-21-87 1Y-4 Static Well Pressure Report 3-3-87 Alaska Oil & Gas Cons. Commission Anclmraoe Receipt Acknowledged; Date DISTRIBUTION: BP Chevron Mobil SAPC Unocal State of Alaska D&M ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Alaska, Inc/--- .... Post Offict ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DAT~:: 10-22-85 TtCA/qSMITTAL NO: 5410 RETURN TO: Al{CO ALASKA, INC. KUPARUK OPERATIONS. ENGINEEI{ING kECORDS CLERK ATO-1115B ' ' '- · P.O. BOX 100360 ~'-~"~ :' , -ANCHORAGE, AK 99'510 - TRANSMITTED ~EI~J~WITH AKE %'~: FOLL~%4ING I'£EblS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSHITTAL. FINAL PRINTS/ SCHL/ ONe'. * OF EACH CEMENT. BOND LOG/ VARIABLE DENSITY " '~w3B-8 -: 06-06-85.~ . .RUN #1 5850-8369 ~ q2X-15 11-07-.84 RUN ~1 5900-8258 . '~2X-1.3~ 11-17-84 RUN gl ~2X-12 12-08-84 ' RUN #1 'w2X-ll 12-08-84' -RUN #1 ,~X-10 12-21-84 kUN '~ 2X-9 12-20-84 PJJN '~2W-6 - 11-25-85 RUN '~2V-16 · 06-06-85 ' kUN '~2V'15 ':-~ 06-07-85..i. RUN ~2V-13' :.--06-03-85- ~'~ RUN · -~'w2U- 7-.'~ii~-; ~: O 4- 01- I~ 5 ~' ' ~UN . ~ 1 -. '"' 20-6.:~?~i' 03-31-85 '~ RUN 03-0=-s5 2D~6:~:~ 12-~9-84 '- kON ~ - ~2Dil_.:~:/;;~ 1~-03-84 . RUN ~lR-8 ~ '~ 06-17-85 kUN. '~lR-7--~' 06-08-~5 - ~UN -~R-5.-;:'~' 06-08-85 - dUN ,~lL-15 .1~-05-84. RUN ~lQ-15 ~' 05-27-85. RUN '~1~3' ~ 04-17-85 ~ kUN ~CPF-~A- ~2-21-84 ~UN C~ENT EV~UATION. ~OOL LUGS/_ ~lF~16' ' 03-12-85 'RUN -~a-5.~:::~ 06-26-85 'RUN ' vla-5 )-.?~?. 06-27-85'-:.~:: ~UN 92 - ~ ~2U-2 :(~::--;~-~ 03-25-85' ~'' "kUN ' '~3~-9'?:';~ ~ 06-30-85 RUN , '~3C'~-~?:-:~ 06-29~85 RUN gl ' --~3C~12:~¥:. 06-29-85-_. : RUN .: . . . . ~CEIPT ACKNOWLEDGED: ' - BPAE- ~':: -:~. -~-; ~ DRILLIN~*B~ . . . B...'CU~XER -. L. J~HNSTON D-& M_-" --' "NSK CLEsK*=L -_ _ _ 5896-8410 3050-7215 310U-6370 3350-6973 5100-8338 5700-7290 4550-710~ 4650-6428 6590-8553 4970-693~ 0070-~122 PLEAS~ ACKNOe4LEDGE 560O-8107 5994-9161 6284-7850 520U-74~9- 3285-6454 5693-6652 5987-8324 4302-7028 6950-8628 4883-6600 6490-7566 ~97~-10744 2200-3856 CkiMENT ~vALuATIUN LOGS 8269-8712 6974-8644 8254-8532 5790-9450 6400-7002 6000-8246 6500-8726 5400-7457 W. PASH~:t{ EXXON PhILLIPs OIL J, RATH~ELL" ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany UNION VAULT/~O*FIL~ - RETURN TQ: ARCO Alaska, Inc~.~..~ Post Offic~~' ; 100360 Anchorage, Alaska 99510-0363 Telephone 907 276 1215 DATE: 08-16-85 TRANSMITTAL NO: 5254 ARCO ALASKA, INC. KUPAi{UK OPEK~TIONS ENGINEERING RECORDS CLERK " ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED ~ERE~ITH ARE THE R~ECEIPT AND RETURN ONE SIGNED PRESSURE FINALS FOLLOWING IT~,]S. PLEASE ACKNOWLEDGE COPY OF THIS TRANSMITTAL. CAMCO lB-3 PBU 04-21/22-85 1D-8 STATIC 04-29-85 1E-5 PBU 04-26-28-85 1H-6 STA?IC 04-29-85 1L-2 PBU 04-24/25-85 1L-5 PBU 04-28/29/85 lQ-6 PRESSURE FALL 'OFF 05-07-85 lQ-9 PBU 05-12/13-85 2A-5 PRESSURE FALL OFF 04-21/22-85 .' 05-05-85 04-24/25-85 04-14-85 04-19/20-85 04-13/14-85 04-17-85 04-29-85 05-02-85 "-05-03-85 05-04-85 05-04-85 04-25/26-85 07-04-S5 06-30-85 07-27-85 06-25-85 06-22-85 06-22-85 07-26-85 06-28-85 06-28-85 2A-5 2C-4 2F-7 2F-8 2F-9 2G-1 2G-1 20-5 20-6 2U-7 20-8 2X-'l 0 OTIS 2A-2 ' 2U-14 ' 2V-2 2V-5 2V-13 2V- 14 w-7 3B-8 i RECEIPT STATIC PBU PBU PBU PBU STATIC PBU STATIC STATIC STA?IC STATIC PBU STATIC PBU PBU PBU STATIC STATIC PBU STATIC. STATIC ACKNO~LEDGED: 3~ P AL'*~ B. CURRIER C~EVRON* D & M* DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON 'MOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* ,j'.--I~ .... F ......... ,'Ir Anch0ra.~-~ STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 10, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are 2U-4 2U-6 the Well Completion If you have any questions, Sincerely, ~. Grube~~~ Associate Engineer please JG/tw GRU10/L59 Enclosures Reports for the following wells: call me at 263-4944. RECEIVED JUL 1 2 ]~85 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichtieldCompany RETURN TO: ",a, Inc. . _. Office Box 100360 Anchorage, Alaska 99510-0360 ARC(' Telephone 907 276 1215 ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 AK 99510 ' AS~HORAGE, ~.~ ~ F.: 06-19-85 TRANSMITTAL NO: 5230 PAGE 2 OF 2 ENGINEERING TRANSMITTED HEREWITH ARE THE FOL RECEIPT AND RETURN ONE SIGNED CO ***CONTINUED. FROM PREVIOUS PAGE* 2D-5 FLOWING BHP ETC-05-06-85 2D-3 ACID JOB PREP 05-0 7-85 2D-3 ACIDIZE 'C'SD 05-11-85 26-9 G.R. SBHP 06-11-85 26-13 SBHP 06-10-85 26-14 SBHP 06-10-85 26-15 SBHP 06-09-85 2G-1 FLOWING BHP 04-2 9-85 2H-1 BHP&TCL 05-27-85 2H-15 SBHP & ETC. 04-29-85 2H-1 BHP & ETC. 05-23-85 2H-3 BHP & ETC. 05-23-85 2H-4 COMP BHP 05-23-85 2H-14 INT. SBHP&ETC 04-28-85 2U-5 SBHP 05-02-85 2U-6 SBHP & TCL 05-0 3-85 2U-7 SBHP PRE PROD 05-04-85 2U-8 SBHP & ETC. 05-04-85 2U-9 PRESSURE TEST 05-27-85 2U-10 BHP SAMPLE 06-05-85 2U-16 'A'SD FLUID ID 06-09-85 2U-16 PBU 06-07-85 2V-10 BHP & ETC. 05-17-85 2V-!l ° STATIC 05-12-85 2V-11 STATIC 05-23-85 2W-13 'C'SD ACID STIM 05-20-85 2X-12 'C'SD ACID JOB 05-12-85 2Z-2 E/LINE FLUID ID 05-03-85 LOWING PY OF THIS CAMCO BAKE R DOWELL OTIS OTIS OTIS OTIS CAMCO OTIS OTIS CAMCO OTIS OTIS OTIS CAMCO CAMCO CAMCO BAKE R/cAMco OTIS OTIS OTIS OTIS OTIS OTIS OTIS DOWELL DOWELL OTIS/CAMCO ITEMS. PLEASE ACKNOWLEDGE TRANSMITTAL. RECEIPT ACKNOWLEDGED: B PAE* B. CURRIER CHEVRON * D & M DRILLING L. JOHNSTON MOBIL* NSK CLERK · 1// .,,~ . .~ . ...... DATE: DIS TRIB UT ION: W. PASHER EXXON PHILLIPS OIL* J. RATHMELL STATE OF ALASKA SOHIO* UNION* K.TULIN/VAULT STATE OF ALASKA ' ' " ALASKA (,- _AND GAS CONSERVATION CO. AISSION WELL COMPLETION OR RECOMI LETION REPORT AND LOC 1. Status of Well Classification of Service Well OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-19 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50_ 029-21282 ', 4. Location of well at surface 9. Unit or Lease Name 546' FSL, 718' FWL, Sec.32, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1517' FSL, 1053' FEL, See.6, TllN, RgE, UM 2U-6 At Total Depth 11. Field and Pool 1132' FSL, 1244' FEL, Sec.6, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKB ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 03/07/85 03/1 2/85 03/14/85* N/A feet MSLI 1 i7. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I~o.~t.~r~sssv~t 8286'MD,6151 'TVD 8132'MD,f048'TVD YES [~X NO [] 1799 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP, CNL/LDT/Microlog, Cal, CBL/VDL/GR/CCL, Gyro (GCT) '-23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 215 sx CS II 9-5/8" 36.0# J-55 Surf 3642' 12-1/4" 730 sx Permafrost E & 180 sx Permafrost C 7" 26.0# J-55 Surf 8214' 8-1/2" 375 sx Class G & 250 s~ Permafrost C 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7980' - 8007' 3-1/2" 7816' 7794' & 7528, 7876' - 7906' w/4 spf, 120° phasing 7866' - 7876' 26. ACID, FRACTURE, cEMENT SQUEEZE, ETC. 7850' - 7860' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Well History ',completion details). 7700' - 7754' w/12 sPf, 120° Phasing 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure =CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. CF'jD Cons 'nchor~oe C°ntrnission Form 10-407 * NOTE: Tubing was run and the well perforated 4/23/85. GRU10/WC10 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30. · . GEOLOGIC MARKERS ' ' FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7701' 575~' N/A Base Upper Sand 775a,~ 5791' 'Top Lower Sand 7830' 58/+/+' Base' Lower Sand 8010' 5966' , : ; . : 31. LIST OF ATTACHMENTS . Addendum ~ . . 32. I hereby, certify that the foregoing is true and correct to the best of my knowledge Signed {~ ~.~.~-,'/ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ' ' Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 4/02/85 2U-6 RU & rn GCT f/8075'-surf. f/8107'-5600'. Rn 6.125" Rn CBL/VDL/GR/CCL gage ring to PBTD. Drilling ~uperintendent Date ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE' 06-27-85 TRANSMITTAL NO: 5228 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 · ANCIIORAGE, AK 99510 /..-~' · FQI,.~,,_T.~D LERE,~_,.! AR .... E FOLLOWING ITEMS. ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS ~NSMITTAL. OPEN HOLE FINALS/SCIIL (ONE * OF EACH LISTE[~ BELOW.) 2UL6 '~5" .DIL/SFL-GR 03-12-85 RUN ~1 3644-8280 '7-2" DIL/SFL-GR 03-12-85 RUN #1 3644-8280 " DEN/NE U--PORO 03-12-85 RUN #1 7500-8253 " DEN/NEU--PORO 03-12-85 RUN ~1 7500-8253 " DEN/NEU--RAW 03-12-85 RUN ~1 7500-8253 ~2" DEN/NEU--F~W 03-12-85 RUN 91 7500-8253 " MICROLOG 03-12-85 RUN ~1 7500-8213 . C OLOG / 75oo- o *PLEASE NOTE THAT THE FOLLOWING LOGS ARE "TWO RUNS IN ONE".THNX (WITH THE EXCEPTION OF THE FIRST ~O.) (Please note that some of the 2" 2U-6 are extremely thin. 2D-15 -/-DUAL DIPMETER-GR 11-22-84 RUN #2 3177-6584 .~-CYBERDI P 11-22-84 RUN ~2 3177-6584 ,/~CMPTR PROCESSED 11-13-84 RUN ~1 2600-3150 11-22-84 RUN t~2 6100-6550 '~5" BHC SONIC 11-13-84 RUN #1 0113-3152 11-22-84 RUN ~2 3177-6582 2" B[iC SONIC 11-13-84 RUN ~1 0113-3152 11-22-84 RUN 4~2 3177-6582 -~'~" CO?4P/NEU/DEN-RAW 11-13-84 RUN ~1 0113-3176 11-22-84 RUN ~12 3177-6564 '/--2" COMP / NI~U/DEN-RAW 11-13-84 RUN #1 0113-3176 11-22-84 RUN ~,2 3177-6564 ~ '5" COMP/NEU/DEN-PORO 11-13-84 RUN ~1 0113-3176 _. 11-22-84 RUN ~2 3177-6564 2" COMP/NEU/DEN-PORO 11-13-84 RUN ,~1 0113-3176 11-22-84 RUN 4t2 3177-6564 5" DIL/SFL 11-13-84 RUN ~1 11-22-84 RUN #2 '-~-2" DIL/SFL 11-13-84 RUN #1 !1-22-$4 RUN ,~2 RECEIVED ~...,., :3!7~?-6.5'9<)~_ ~.~.,C. '"' :'":' ,,- . /.~ ./ ~ - ¥,. 3177-6590 Anch0rag~ DATE: DISTRIBUTION: ~" ?AE DTM,',±LLINC*i~L- W. PASHER B CURR-' E '~ ~', JOll,'~c"'r~",~ . ~ ,~ ..... ~, EXXON C[;EVkON ~qOEiL PHILLIPS OIL · , ~, CLu .... '~!, J ELL*BL STATE OF ALASKA*EL SOHIO /SE UNION ARCO Alaska, Inc. --~"'"'. Post Office Box .60 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 10, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas COnservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the 2C-16 2D-10 2D-13 2G-16 lQ-8 2U-6 If you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw GRU9/L41 Enclosures following wells' 263-4944. · Alaska 0il & Gas Dons. i;0mmission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .---. STATE Of ALASKA ~ ALASKA C . AND GAS CONSERVATION CO, 'IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [-I SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-19 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21282 4. Location of well at surface 9. Unit or Lease Name 546' FSL, 718' FWL, Sec.32, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1517' FSL, 1053' FEL, Sec.6, T11N, RgE, UM 2U-6 At Total Depth 11. Field and Pool 1132' FSL, 1244' FEL, Sec.6, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKB ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 03/07/85 03/12/85 03/14/85'J N/A feet MSLJ 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8286'MD,6151 'TVD 8132'MD,6048'TVD YES [~X NO [] 1799 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, CNL/LDT/Microlog, Cal, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 215 sx CS II 9-5/8" 36.0# J-55 Surf 3642' 12-1/4" 730 sx Permafrost E & [80 sx Permafrost C 7" 26.0# J-55 Surf 8214' 8-1/2" 375 sx Class G & 250 s) Permafrost C · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7980' - 8007' 3-1/2" 7816' 7794' & 7528' 7876' - 7906' 7866' - 7876' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7850' - 7860' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Well Hi stor), (completion) 7700' - 7754' w/12 spf, 120° phasing 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.} I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZEIGAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chips. E C JUN Z Alaska 0il & Gas 00r~-~. C0r;ur~i::;si~n Anchorag~ Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run & the well perforated 4/23/85. CONTINUED ON REVERSE SIDE GRUg/Wc29 Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, . . MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7701' · 575z,~ N/A ' Base Upper Sand 7754' 5791' · Top Lower Sand 7830' 58z~4' "' Base Lower Sand 8010' 5966' · · ~ ,. 31. LIST OF ATTACHMENTS ~ , . : . ' 32. I hereby certify that the foregoing is true and correct to the bes~. of my knowledge · ;.. -' Signed ~l ~ ~L~c~l-,/ Title Associate Engineer Date // INSTRUCTIONS , General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and:leases in Alaska-. -.., . ~- . : , Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air iniection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". · . . . ARCO Oil and Gas Company Daily Well History-Final Report Inslructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish I State Alaska North Slope Borough I Alaska Field Lease or Unit Well no. Kuparuk River ADL 25644 2U-6 Auth. or W.O. no. T t e AFE 603635 Completion WWS #1 API 50-029-21282 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 4/21/85 Complete record for each day reported Date and depth as of 8:00 a.m. 4/21/85 thru 4/22/85 4/23/85 5/07/85 Old TD Released rig I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our J Prior status if a W.O. I 0800 hrs 7" @ 8214' 8132' PBTD, PU WD Pkr 11.1 ppg NaC1/NaBr Accept rig @ 0800 hrs, 4/21/85. ND tree, NU & tst BOPE. RU DA, RIH w/gun #1, 4", 4 SPF, 120° phasing, perf 7987'-8007'. RIH w/g~n #2, 4", 4 SPF, 120° phasing, perf 7980'-7987' & 79~6'-7~f14'. RIH w/gun #3, 4", 4 SPF, 120° phasing, perf 78~6'-7906'. RIH w/gun #4, 4", 4 SPF, 120° Phasing, perf 7876'-7886". RIH w/gun #5, 4", 4 SPF, 120° phasing, perf 7886'-7896' & 7860'-7876'. RIH w/gun #6, 4", 4 SPF, 120° phasing, perf 7850'-7860'. RIH w/gun-#7, 5" 12 SPF, 120° phasing, perf 7734'-7754'. _RIH w/gun #8, 5", 12 SPF, 120° phasing, perf 7720'-7734'. RIH w/gun #9, 5", 12 SPF, 120° phasing, perf 7700'-7720'. RIH w/gage ring/JB, rn #1, rec'd rubber. RIH w/gauge ring & JB, rn #2, rec'd cmt. RIH w/gage ring & JB, rn #3. RIH w/WL pkr. 0500 hrs. Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Sing-le Producing method Official rese~oir name(s) - Flowing Kuparuk Sands Potential test data 7" @ 8214' 8132' PBTD, RR Crude/Diesel RIH w/pkr, set @ 7787'. RIH w/239 jts, 3½", 9.3#, J-55 EUE, 8RD IPC tbg. Set top pkr, shear SBR, lnd tbg. ND BOPE. NU & tst tree. Displ well to crude. Set BPV. RR @ 0500 hrs, 4/23/85. SSSV @ 1799' - Top Pkr @ 7528' - "D" Nipple @ 7808' - Tailpipe @ 78~6'. I Frac well w/346 bbls gelled diesel in 7 stages w/700# 100 mesh & 14,900# 20/40 mesh. NewTO ]!P. Dep,h 8132' P~TD Date Kind of rig 4/23/85 Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day ECE' VED Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date ,~l~km 3ii & Gas ;(ins. 13ommissi]n The above is correct Signature Date Title _/~_~_ ~ J 5/20/85 I Drilling Superintendent For form preparation and distribu~n, see Procedures Manual, Section 1'0, Drilling, Pages 86 and 87. ARCO Alaska, Inc.' Post Of lice b~x 100360 Anchorage. Alaska 99510-03G0 Telephone 907 276 1215 DATE:05-29-S5 TRANSMITTAL NO'5199 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 AI'.CHORAGE, AK 99510 T tQ\NSM I'"m~ r~ -'-,.~, tlEREWITIi ARE TIIE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK ~,~ELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH)- 2A-4 04-22-85 2A-7 04-23-85 2F-6 03-21-85 2G-8 03-21-85 2G-!2 03-23-85 2H-13 04-26-85 2][-14 04-2 8-85 2H-15 04-29-85 2U-1 04-11-85 2U-2 04-11-85 2[]-3 04-11-85 2U-4 04-11-85 2U-5 05-02-85 2U-6 05-03-85 2U-7 05-04-85 2U-8 05-04-85 2U-13 03-09-85 2U-14 03-21-85 2U-!5 03-20-85 2U-!6 03-15-85 2V-2 03-23-85 2V-SA 03-17-85 2V-SA 01-24-85 2W-4 04-13-85 2X-! 04-14-85 ~.X-$ 04-~_,-~'~ 85 2X-13 03-30-85 STATIC-'C' SAND STATIC-'A' & 'C' SAND STATIC-PBU-'A' SAND PBU-'A' SAND STATIC-PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND ~eTATIC-'A' SAND PBU-'A' SAND PBU-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND STATIC-'A' SAND ST~.'~¥C-'A' SAND STATIC-'A' SAND STATIC STATIC-'A' &'C' SAND STATIC-'A'&'C' SAND STATIC-'A'&'C' SAND STATiC-'C' SAND STATIC-'C' SAND STATIC-'A' &'C' SAND c'"""~ IC- 'A ' o ~ ~i SAND STAT!C-'A'&'C' SAND STATIC-'A' &'C' SAND PBU-'A' SAND ~ EC.EIPT ACKNOWLEDGED: DRILLING L. JOIINSTON MOB t L * ~:SK CLERK DISTRIBUTION: W. PASHER EXY-ON PUiLLIPS OIL* J. RATH~[ELL* ARCO Alaska, Inc. Post Office b,.,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 24, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2U-6 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 2U-6. I have not yet received the well history (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer · JG/tw GRU9/L07 Enclosure RECEIVED MAY 3 0 2985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~---- STATE OF ALASKA r--. ALASKA ~AND GAS CONSERVATION C(. MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-19 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21282 4. Location of well at surface L,~, ~,J, ,S " ~ ~,~.~,~,, · 9. Unit or Lease Name 546' FSL, 718' FWL, Se0.32, T12N, RgE, UM i w~''~l, Kuparuk River Unit At Top Producing Interval i Surf.~ 10. Well Number At Total Depth ' . 11. Field and Pool 1132' FSL, 1244' FEL, Sec.6, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 106' RKBJ ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 03/07/85 03/12/85 03/14/85*I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8286'MD,6151'TVD 8132'MD,6048'TVD YES r~x NO []I 1799 feetMD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, CNL/LDT/Microlog, Cal, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SiZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 215 sx CS II 9-5/8" 36.0# J-55 Surf 3642' 12-1/4" 730 sx Permafrost E & 1180 sx Permafrost C 7" 26.0# J-55 Surf 8214' 8-1/2" 375 sx Class G & 250 s; Permafrost C 24. Perforations open to Production (MD+TVD of T;3p arid Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7980' - 8007' 3-1/2" 7816' 7794' & 7528' 7876' - 7906' 7866' - 7876' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7850' - 7860' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 7700' - 7754' w/12 spf, 120° phasing 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ' RECEIVED o 1985 Alaska Oil & Gas Cons. Commission Anchora~o Form 10-407 * NOTE: Tubing was run & the well perforated 4/23/85. GRUg/Wc05 Submit induplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKE~RS~" "' '¢ - ' :~ ;; ~' ' "' ') ':' ' FO'RI~/IATION TESTs NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 77017 57541 N/A Base Upper Sand 77547 57917 Top Lower Sand 78301 58447 Base' Lower Sand 80107 59667 · . ,. .. .. 31. LIST OF ATTACHMENTS .. . ,. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge , , -, Signed /~_~ ~Z/~ ~~¢~LJ Title Asso¢'at;e E"~j'neer Date ,.. INSTRUCTIONS .. General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ~ Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". AI~CO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-6 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 2U-6. The tubing details, intervals perforated, bottomhole location, and TVDs will be submitted when the gyroscopic survey has been run and the well completed. If you have any questions, please call me at 263-4944. · , Sincerely, J. Gruber Associate Engineer JG/tw GRU5/LI07 Enclosure RECEIVED APR 1 7 198§ Alas~;a 0it & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~-- ALASKA t .c AND GAS CONSERVATION CO, ...MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-19 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21282 4. Location of well at surface 9. Unit or Lease Name 546' FSL, 718' FWL, 5ec.32, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2U-6 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 106' RKB ADL 25644 ALK 2575 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 03/07/85 03/12/85 03/14/85 N/A feet MS L N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 8286'MD 8132'MD YES [] NO F~XJ N/A feet MDJ 1500' (Approx) 22. Type Electric or Other Logs Run D! L/SFL/GR/SP, CNL/LDT/Mi crol og, Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 105' 24" 215 sx CS II 9-5/8" 36.0# J-55 Surf 3642' 12-1/4" 730 sx Permafrost E & 180 sx Permafrost C 7" 26.0# J-55 Surf 8214' 8-1/2" 375 sx Class G & 250 s: Permafrost C 24. Perforations open to Production (MD+TVD 0f Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD} AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED,a~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONERECEIVED APR 1 7 1985 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 (~RU5/WC47 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE , . , 29. . '~' 30.. " G'EOLOGICMARKERS ' .' '. -"'~. , :, . : 'i;' ': . ' ' ' ' ' ' ·FORMATION~'-"~"~-~b: · : · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT, DEPTH GOR, and time of each phase. N/A N/A " , : . · , , .. . 31. LIST OF ATTACHMENTS ., 32.' .... i'l~;r;~/~certify that the foregoing is true and correct to the best of my knowledge . .- Signed do ~ ~)~J_/~L¢_.~[_~ Title Associate Engineer Date .. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval 'to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the Cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel3e~" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 603635 ICounty. parish or borough North Slope Borough ILease ADL 25644 or Unit ITitle Drill JState Alaska IWell no. 2U-6 Operator Doyon 9 ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 3/07/85 3/08/85 3/09/85 thru 3/11/85 3/12/85 3/13/85 The above is correct API 50-029-21282 Date 3/7/85 Complete record for each day reported Hour 0115 hrs. 16" @ 105' 563', (458'), Drlg Wt. 9.6, PV 20, YP 35, PH 9.0, WL 12, Sol 8 Accept ri~ @ 2215 hrs, 3/6/85. NU 20" diverter sys. @ 0115 hfs, 3/7/85. Drl 12¼" hole to 563'. 16" @ 105' 3241', (2678'), Drlg Wt. 9.6, PV 16, YP 32, PH 9.0, WL 18.6, Sol 9 Drl, DD & surv 12¼" hole to 3241'. 654', Assumed vertical 844', 5.7°, S16.4W, 844 TVD, 9 VS, 9S, 3W 1235', 20.6°, S24.5W, 1235 TVD, 99 VS, 92S, 35W 1451', 27.9°, S17.4W, 1451TVD, 187 VS, 175S, 66W ARCO w.I. JPr or stalus if a W.O. Spud well For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 46.6°, S17W, 2628 TVD, 1341 VS, 1276S, 427W 45.0°, S16.6W, 2969 TVD, 1689 VS, 1612S, 528W 45.2°, S21.0W, 3358 TVD, 2078 VS, 19818, 654W 47.6°, S24.4W, 3698 TVD, 2435 VS, 23118, 792W 47.9°, S31.5W, 4434 TVD, 3229 VS, 3025S, l140W 48.8°, S25.0W, 5144 TVD, 3984 VS, 3695S, 1493W 9-5/8"@ 3642' S266', (656'), Drlg Wt. 10.9, PV 17, YP 11, PH 9.5, WL 6.5, Sol 16 ska Drl & su~ 8~" hole to 7789', had 26 bbls influx. SI well, SICP = 0, SIDPP = 0. Circ 10.8 ppg mud around, well dead. Open well, drl to 8266'. 8286', 46.0°, S23.7W, 6166 T~, 5080 VS, 4695S, 1942W 9-5/8" @ 3642' 8286', (20'), Prep to rn csg Wt. 11.2, PV 14, YP 18, PH 9.5, WL 4.4, Sol 18 Drl 8½" hole to 8286', CBU, 17 bbl gain. Circ gas thru open choke, raise mud wt to 11.1 ppg. Open well -- dead. Short trip, CBU, POH. Rn OHL (DIL/SFL/GR/SP f/8268'-3642', CNL/LDT/Microlog f/8268'-7500', Cal f/8268'-6500'. TIH, CBU, P0H to rn 7" cs$. IDate Title 3101185 Drilling Superintenden~ EIV£D 3132', 3621', 4172', 4665', 5749', 6787', 56.24% 9-5/8" @ 3642' 7610', (4359'), Circ Wt. 10.4, PV 15, YP 13, PH 9.0, WL 6.7, Sol 13 Drl 12¼" hole to 3656', circ hi-vis sweep, CBU, POH. RU & rn 84 its, 9-5/8", 36#, J-55 BTC to 3656'. Cmt w/730 sx PF "E", followed by 880 sx PF "C" w/.65 #/sx PF retarder. Displ using rig pmps, bump plug. CIP @ 0800 hrs, 3/9/85. ND diverter sys, NU &tst BOPE. RIH w/BHA, drl 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 7610'. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official lest is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District Slate Alaska North Slope Borough Alaska Field Kuparuk River Auth. or W.O. no. AFE 603635 Doyon 9 Operator ARCO Alaska, Inc. County or Parish Lease or Unit ITte A.R.Co. W.I. Spudded or W.O. begun Date Spudded Date and depth Complete record for each day reported as of 8:00 a.m. Old TD 3/14/85 3/15/85 Released rig 0945 hrs Classifications (oil, gas, etc.) Oil Producing method Potential test data Flowing ADL 25644 Drill IWell no. 2U-6 API 50-029-21282 rl'otal number of wells (active or inactive) on this 56.24% Icost center prior to plugging and labandonment of this well I IH°ur I Prior status if a W.O. 3/7/85 / 0115 hrs. I / 7" @ 8214' 8132' PBTD, ND BOPE Wt. 11.1, PV 12, YP 8, PH 9.0, WL 4.4, Sol 16 POH, LD DP & BHA. Rn & lnd 204 its, 7", 26#, J-55 BTC csg w/FS @ 8214', FC @ 8132'. Lost rtns w/193 jts in hole. Cmt w/375 sx C1 "G". Displ'd, bump plug. CIP @ 0300 hrs, 3/14/85. Flts did not hold. Hold press on 7" csg. Rel press, no flow back. ND BOPE. RR @ 0945 7" @ 8214' 8132' PBTD, RR 11.1 ppg Brine ND BOPE, NU wellhead & tst pack-off to 3000 psi. hrs, 3~/85. /4 ~ em+- /~ t~o bb/5 ~mhc. 8132' PBTD Rotary /~ EOf/V£D r New TD I PB Depth Date JKind of rig 3/1/85 I Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands ns. Commission ".'.'8 t~la,sA~ Oil & Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day~il/~i)f)r:~ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Elfective date corrected _, The above is correct For form preparation and distribl~on, see Procedures Manual, Section Drilling, Pages 86 and 87. Drilling Superintendent $ UB-$ U~FA GE DIRECTIONAL SURVEY ~] UIDANCE r~] ONTINUOUS ['~'] CO L Company ATLANTIC RICHFIELD COMPANY Well Name Field/Location 2U-6 (546' FSL, 718' FWL~ S32~ T12N,~ RgE~ UM) KUPARUK~ NORTH SLOP,E~ ALASKA Job Reference No. 70341 Lo~ged By: LESNIE Date R E C E IV E D os-~A:~-~o~ MAY 3 0 ]985 Computed By; CUDNEY Alaska 0il & Gas Cons. Commission A,,c.orage CC'I' DiPECTT['~HAL S[JRV~.¥ C{}STij~EP l,i A~C~ AI,ASKa, INC, KUPARUK SLOPE, ALASKA SUPVMY D~TE: 3n-~AR-85 METHODS nF COHPUTA~ION TOOL LnCaTTON: ~AN6ENTXAL- averaqed deviation ana a~lmuth TNTERPOLATI[)~: T,,[M~'AR VMRTICA[, SECTION: HORTZ, DIST, PROJECTED ONTO h %'ARGET AZIMUTH OF &OUTH 23 DEN 17 ~TN ~E51' ARCO ~[J~SKA, THC. 21]-6 KIIPARI;K NORTH SLOPE,ALASKA CO~:PUTATION D ~ '['F.: 4-UAY-85 PACE ~m DAT~; OW SORYFY.' 30-N~R-~5 KEI,LY R[]SMTNG FLF..VATION: 106,00 FT ENGTaEER: LE$~ fF.. INTERPOLATED VALUF.$ Fr~R EVE~' 100 F~JFT JIF MESSURF.'D DF. PT}{ T~U~ SUB-SEA COL:RSF MEASURFD VERTICAL VERTICAL DEV~ATIOh A~IWUT~ DEPTH D~P?H DEPTH DE~ MTN I)FG MTN 0.00 100,00 200.00 300.00 400.00 500.00 600.00 700.O0 0 O0 -106.00 100 O0 -~.00 200 On 94 O0 300 O0 194:00 400 00 ~94,00 500 00 394,00 600 00 494.00 ~09 99 ~93.99 800,00 709,9] gO0 O0 809,4{ 1000:O0 997,97 1100,O0 1005.10 ~0o 00 1190,56 1300:00 1284,0o 1400.00 1.375.03 500.00 1463,53 ~600.00 1548,71 1700,00 1630'51 0.00 0,00 0.00 N C,O0 ~' 0.00 N 0 O k. -o.19 0,11 O.lO N C,06 F 0,20 N 18 34 g -0.50 0,15 O,4q ~ 0,13 F 0,51 N 14 45 E -0.64 0.O5 0,71 ~J O,0] W 0,71 N 2 42 W -0.63 0,14 0,~8 ~ C,16 W 0 78 h 12 1~" ~ -o.~2 0,0~ 0,9~ ~ 0,20 w 1:00 n il t'~ ~ -1.O7 0.66 1,24 ~ 0 20 W 1,26 N 8 5'; ~ -0,{7 0,89 0,36 ~ 0:49 W 0,56 N 49 14 ~ 18 S! W l?.~ 2:83 !.9 55 W 20.6() 4,17 1.6 55 W 5].t. 9 4,05 i4 16 W 87.64 3,31 16 30 W ~17.~7 3.37 ~6 57 W ~58.94 3,23 17 46 W 205.18 4 13 ~9 9 W 257.35 18 47 W 31~.69 1.99 69~,q3 3 10 793,41 7 4R R91.07 11 46 989,10 15 30 1084,5b 19 4 1178.00 22 37 1~6q,03 76 5 1357,53 79 3] 1442,71 33 31. 1524.51 36 1~ 1800 O0 1710 O~ 1604 08 38 46 1900;00 1785 98 1670:98 42 27 2000.00 1857 210o;00 i925 2~00 O0 J, 991 2300:o0 2058 2400,00 2125 2500.00 ~lq2 2600 o0 2259 2700~00 ~326 18 40 w 37K.n6 18 27 W 430.q0 17 53 W 587,09 17 4] W 657,~5 ~7 27 W 731.]8 1'1 1.6 W 805.~0 !7 36 W 870.09 !7 55 W g57.03 43 1751,43 46 g 05 1810'n5 48 11 54 ln85.Sq 48 15 25 1957,95 48 !. 26 2010.76 47 57 22 2086.22 d7 56 27 2153,27 47 46 71 2220.71 ~7 2] 2800,00 2304 04 2?88.64 46 59 900.00 2463 1~ 2357.1,2 46 30 I000,00 25tl 3100,00 2600 3~00,00 2668 300 O0 ~718 14oo:oo ,o7 3500 o0 2877 $600~00 2948 3700,00 t019 S .17 5J W 1026,45 62 2425.62 46 50 1~ 2494,18 46 36 9~ 2562.92 46 27 00 2639.00 a6 4 68 2701,68 45 38 84 277'.84 45 14 2~47,49 44 5O 61, 2g13.61 44 4] !'7 46 W 1099,50 1'7 41 W 1172,02 17 38 W 1244,.54 17 )0 W 1316,o7 17 2~ W 1~89.~3 17 20 W 1461,16 !'7 26 W 1532.51 17 30 W 1603.40 17 34 W 1673.a2 17 36 W 174t.77 2.74 12 22 28 06 50 50 79 23 113 53 153 07 197 5~ 247 0fl 301 48 1,19 W 2 98 5 23 24 w 4.06 W 12 87 $ 1~ 22 W 9,68 W 29 68 S Iq 2 ~ 17.27 W 53 35 S IR 49 ~ 24,94. W 83 07 S 17 28 V~ 34,38 W 118.6~ $ 16 50 W 46.36 W 159'94 $ 16 51 W 60 05 W 206 4& $ ]6 54 ~ 95.51 W 316'25 S 17 ]4 , 37 3'01 ,.. 3 ~3 0i59 0 ~0 0,45 0,20 0,48 0 2O 0~33 358.8~ S 1!5.02 W 376,80 5 17 46 ~ 420.52 S 135,67 W 441,86 ~ 1.7 52 ~ 486 96 $ 157,48 W 511,79 $ 17 55 ~: 557 0] $ 18~,18 W 585,45 $ 17 55 ~ 6~8 15 S 203 0~ W 660,14 ~ 17 5~ '~ 699 16 S 295 55 W 734 64 ~ 17 52 N 770 Ol S 247 67 W 808 86 S 17 49". 981 79 S 315.24 W 1031 16 S 17 48 ~ 0,46 0,18 0.28 O 34 0 65 0 47 0 45 0 5~ 0 35 1051,66 S 337,6g W 1104,54 $ 17 48 ~ 1121,06 S 359,87 ~.! 1177,41 S 1.7 47 W 1190,48 S 382,01 W 1250,27 S 17 47 ~ 1259 88 S 403 90 W 1323,06 S 1.7 46 W 1379 15 S 495 8~ ~ 1395,69 S 17 45 ~ 1398 1~ $ 447 51 w 1467 99 S 17 44 ~ 1466 54 S 4~9 04 ~ 1539 7~ 8'17 44 w 1534 51 $ 490 4~ W 1610 97 S 17 d3 ~ 1602,00 S 511 7~ W 1681 75 $ 17 ~2 ~ 1669.01S 532 98 w !752 04 S 17 42 ~ 2II,-6 NORTH SLOPE,ALASKA CBMPbTAq'I~N OAT~: zl-mAY-g5 PAGk 2 DATE OF SURVEY: 30-MAR-ES KEf,bY RUSHING E~EVATTON: 10b.00 Fl' ENGI'NEf, R: LESNIE INTERPOLATED VALdE$ FOR EVEN 100 PE~'r L)F ME~S[IRFO DEPTH T~UM SUR-SE~ COURSF MEASURFO VERTICAL VERTICAb DEVIATION AZIM~]Ta DEPTH DMPTH ~EPTH DEG MIN DFG ~IN 3800.00 30q0.5~ 2q~4.58 44 48 3q00,00 31~1.6~ 3055,63 44 36 4000,00 ]232 75 3126,75 44 43 4100,00 ]303 6R 3197.68 45 5 4200,00 3373 4300,00 t443 4400,00 3512 4500,00 35~0 4600,00 3647 4700.00 ~714 94 3967,94 45 31 74 3~37.74 46 5 b4 3406.64 46 57 11 3474,11 47 26 3541 ~6 47 44 6~ 360~63 47 37 4R00,00 3782 07 3676,07 47 34 4900.00 3849 57 3743.57 47 30 5000,00 3917 15 3811,15 47 24 5100 00 39~4 84 387~.84 47 20 5~00:00 4052 77 3g46.77 47 4 5300.00 41g'.0" 4015.08 46 4~ 54 oo.oo 5800 00 446~ $5 4357.35 47 40 6000, .00 4560,42 2~ 4629,~2 5900 O0 45~0 O0 4598 6100 4666 6~00 00 47~5 6300i00 4805 6400 O0 a875 6500 O0 4945 66(10i00 ~015 6700 O0 5083 62 4424 62 47 36 24 449~4 47 25 4~ 46 82 45 51 6] 4699 63 45 39 53 4769~53 45 39 51 4~30~51 45 31 41 4~09,41 46 15 48 4977,48 47 25 6800 O0 5150 91 5044.01 48 2~ 6900~00 521.6 1~ 5110 12 49 57 7000.00 5280 27 5174~27 50 7100,'00 ~344 8~ 5~38.~2 a9 30 7200.00 5410 24 5304,24 48 47 7~00 00 5476 54 5370,54 48 7400 00 5544 22 5438,22 46 48 7500 O0 5613 23 5507,~3 45 50 7600 O0 5682 ~7 5576,87 45 44 7700 O0 5753 08 5647,08 45 23 SECTION SEV~:RITy NORTH/SOOTH EAST/WEST DIST. FEET DE~/1 00 FEEl' FEFT FEET DEC S 17 30 W l@IS.P8 $ ~.7 43 W lP83.02 S 17 45 w 195].P8 $ 18 42 w 2024.06 S ~1 2! W 2095,!2 $ 73 36 w 2166.70 $ 95 3~ w 2230.!5 S 96 1 W 2]17,~7 S ~5 55 w 2386.90 ~ 75 48 W 2460.72 0.25 0.17 0,10 2,26 1,10 2,71 1,53 0,27 0.28 0.14 1736.15 S 554,30 W 1822 49 S 17 42 ~ 1803,1u $ 575,79 W 1892 87 S 17 42 w 1870,14 S 597,15 W 1963 16 S 17 42 ~ 1'937.2~ R 618,80 W ~033 65 $ 17 42 ~ 2003,99 S 643,40 w 2104 74 $ 17 ~ ~ 2070,26 S 670,49 W 2176 13 $ 17~ a ?135,98 $ 701.05 W 9248 08 S 1~ 10 ~ .34 S 2391 23 $ 18 75 ~ 2202 .733,34 W 2268,94 S 7~5,80 W ~394 69 8 18 ]9 w ~335,~5 S 79~,05 W ~468,04 $ 18 5! ~ S ~5 40 w 2534.48 $ 95 27 W 2608.91 S 75 2t W 2681.86 S ~5 23 W 2755,42 ~ ~5 27 W 2828.76 $ 75 3~ W 2901.73 $ ~5 36 W 2974,36 $ 25 45 W 3046.66 g 97 13 W ~119,09 S ~7 50 W 319.1,8~ 0.25 0.30 0,11 0,28 0.34' 0,30 0,23 0,37 2.08 0,80 2401.94 S 830.15 246~.52 $ 861,97 W 2~14 9535 09 $ 803,59 W ~687 ~b0l 50 S 9)5 15 W 776l ~667 ~? s 956~64 w ~834 9733 7~ S 988,10 W ~906 ~799 35 S 1019,47 W 9979 9W64 57 $ ~050.8~ W 3051 ~9~9 65 S 1082,81%f 3123 ?994 W 2541 ]5 ~ lq 3 ~ 6~ S 19 14 w 97 S lO 25 m 19 5 1~ 3,4 ~ 21 $ 10 43 ~ 87 6 19 52 W 21 5 20 0 W 22 S 20 ~ ~ 35 S 20 17 W 22 $ I116,92 w 3195,76 S 20 ~7 ~ ~ 97 17 W 3339.26 q 27 4 W 3412.77 ~ ~6 59 W 3~85.75 K ~6 5~ W ~557,6! $ 96 50 W ~629 07 $ 26 50 W ]700:45 S ~6 49 W ,3771i 74 S ?6 47 W 3843.12 $ ~7 20 w 0.48 1.01 0,53 1 07 0:35 0,29 O, 14 0,06 2,04 0,77 312:t,9~ $ 1.1~6 3190,52 S 1219 3255.66 S 1252 3319,86 S ~285 3383.74 $ 1317 3447.5~ S 1350 .3511 29 S 1.382 3575:12 $ 1414 3649.38 $ 1447 50 S 1151 50 W 3269 05 W 3342 57 W 341.5 67 85 W 3488 44 W 3560 03 S 21 77 W 3631 20 06 W 3702,.47 3~ W 3773,59 S 55 W 3844,]9 83' W 3917,/3 S S 26 31 W 3980,89 $ ~6 27 W 4065,59 $ 26 53 W 414~,15 $ ?6 30 W ,t218.39 $ 96 ~ W 4293,02 S 75 21 W ~36~,71 M ~ 59 W 444~.~9 s ~4 28 w .1514 63 S 24 14 W ,i586:38 S ~5 2i W i657.57 2 26 1~.30 0,75 0,~4 0 81 ! 12 0 89 0 57 0 9O ! 2~ 3705 11 S 1.481 47 W 3991,25 $ 21 47 W 3774 0q S 1514 99 W 4066,8~ 6 21 52 W 3842 54 S ~5~9 65 W 4143,~7 , 39~0 3978 404~ 4112 4178 424~ 4308 25 S 21 57 ~ 78'$ 1583 95 W 4219 6 22 2 '~ 57 S 1617 48 W 4204,79 5 22 7 W 04 S 16.49,9~ w 4369,5.1 S 29 1.1 e; 68 S 16R1,18 W 4443,03 $ 2~ 14 w 39 S 1711,48 W 4515,32 5 27 16 W 80 S ~741,0~ W 4587,04 S 2~ ~8 ~ 53 S 1770,70 W 4658,20 6 22 ~0 ~ PA~ ~ ARCR AbASKA, [NC, 2tI'6 NORTH SLOPE,ALASKA DATE O~ SUqVEY: ~O-MAR-85 ENGTNFER: bF~NIE lOb,O0 Fr .[NTERPO[.,ATED VA[IUE$ E;OP,. EVEN 1',)0 FEinT dr"' MEA,.STIRED DEPTH TRUE SUB-SEA COUPSF ME~IIRFD VFRTICAL VERT~CAb DEVIATION A~IMdTH DEPTH DEPTH DEPTH DEG VE~TTC,~L DOqL, EG RFCTA~G~IL~R COOR!)Trt~fF,$ HORTZ, FEET DEC/1 O0 FE~T FE.~T FEET DEC ~1~ 7~00.00 5822,86 5716,86 46 { 7qO0,oO 5891,90 5785o~0 46 53 8000 O0 5959 59 5,5~,52 ,7 45 890~,00 60~3,~ 5987,~2 48 6 8~86,00 6150,74 6044,74 48 6 q 75 43 W 4720.!4 ~ 95 5~. W 4~01.4.1 $ ~7 1~ W 4940.~7 ~ 97 1~ W 3023.]3 S 27 1~ W b087.~9 0,6~ 1.3~ 0,6P 0,00 0.00 0,00 4373.17 S 1~01.66 W 47~9,11 ,5 2? 93 ~ 4438,1~ S !~{3,2g w 4801 92 $ 2? ~u ~.~ 4604,46 S !865.45 W 4875 .t6 $ 22 ~9 w a570,76 S 1898.77 W 6949 47 S 2~ 33 ~; 4bq.~'lg S 1962,31 w 5087 ,17 5 22aL.. , CD~PUTATI. nN DATE: 4-~A¥-95 P AC.,E 4 ARC~ AbASKA, TNC, NORTH SI,OPE,AI, A~K~ DATE; OF' SURVEY; 30-HAR-85 KELLY 8USHTi~G ~',bEVATION: 106,00 FT INI'~RPOLATED VA~,UFS F~R EVE~I ~0~U F,~:ET O~' ,~EA$iJ~ED DEPT TRU~ SUR'SEA COURSF MEASURED YFRTICA~, VEDTICAL DEVIATION AXI~UTH. DEPTH D~PTH DEPTH DEG ViCRTTCAU I") O ,; L F, ,,:'; RECTANGII~,AN CP.O~I)TNATF.$ HOHIZ. ,:{ECTI~N ~gVERIT¥ I'4ORTFI/$C3UTH EAST/WEST FF, ET DE;]/{ 00 F ~jF'f FE~T FEET 0.00 0.0n -tO6.00 0 0 1000.00 9q7.97 89~.97 ~1 46 2000.00 1.857.4~ 1~51.43 46 q ~00.00 ~531,62 2425.62 46 50 4000.00 32~2.7~ 3126.75 44 4] 500~.~0 ~9~7.15 3~11.~5 47 24 600~.o0 4598.24 4492.24 47 25 7000.00 K2RO,27 5174,~7 50 ~, 8000.00 5959,52 585].52 47 45 N 0 0 F 0.00 S 19 55 w 2q.60 $ ~ 1 w 509,55 S 17 38 W t2~4.~4 S ~,7 4~ w iq$~.R8 $ ?5 2~ W 2681.~6 $ 27 4 W 3412.77 S ?6 5~ W ~47.15 S ~6 4 W '~75.00 0.00 4 17 3[33 0 2~ 0 10 0.53 0.75 0,62 0 O0 ~) 0,00 K 0 O0 N 0 0 9.8~06 S 9.68 W 29 68 ,tS'lc} 2 485,96 ~ 1.57.48 W 511 79 ~ 17 55 w 11q0,4~ $ 382.01 w 1250 27 $ 17 47 w 1.870.14 S 597 15 W ~.96] 16 S 17 25"~5,09 S 8Q3:59 W 9.68'1 97 S 19 ?.( , ]1q!),59. S 12~9 57 W ~4~.5 67 S 20 55 384'2,54 S }54.9:65 W 4J4] .25 6 21 57 45r~-~,46 S-1~65'45 w 4875,46 $ 22. 8~86.00 6150.74 6044.74 48 6 S ~7 18 W bn87.19 0.00 4bq3,79 S 1962,31 W 5087,47 2tI-6 COMPUTA'{'ION D~'CF: 4-faAY-}) 5 PACE 5 DATE l)F SUItV.F,Y: ]0-~AR-85 K~]I,bY ~USHING ~(~EVATION[ lob,00 FT INTERPOLATED VAL[JFS f'O~ EVEN 100 FEET OF SU~-SEA DEPTH SFC~ION SEVERITY NORTH/SOUTH E~ST/WEST DIST, FFET DE~/] O0 FEET FE~T FEET D~iG ~I~ TRUE SUB-$E~ COU~SF ~EASURED VFRTICAL VE~T?CAL DEVIATION AZI"UTh DEPTM D~PTH DEPTH DEG MIN D~G ~IN 0.00 0,00 -10~.00 0 0 N 0 0 F 6.?0 6,on -tOn,O0 0 0 g 0 34 w 106 O0 106,00 0,00 0 8 N 18 BO W ?06~00 206,00 100,00 0 13 ~.!2 ? ~ ]06,00 306.0n ~00,00 0 7 ~; 87 ~ W ~06.00 406,00 ]00,00 0 5 N 18 0 W 506.00 506,00 40o.nO 0 1~ ~' 5 15 w 606,00 606,0n ~00.00 0 ] $ 45 36 F 706.01 706,00 600.00 1 9 S 13 5~ W ~06,08 806 O0 ?00,00 3 2n S 14 41 W a06,&5 906:0n ,On,O0 8 0 ~ 19 2 W 100~,22 1006,00 O00,O0 12 6 ~ 19 45 W 1111,30 ~106,00 1000,00 15 56 $ 1.6 26 W 1216,38 1206,00 1100,00 19 37 S 14 31. W 132],00 1306,00 1~00,00 23 21 S 16 45 w 1434,64 1406,00 1]On,O0 ~7 14 $ 17 1 W 1549,77 }506,00 1400.00 31 31 $ 18 48 W 1660 71 1606,00 1,500,00 35 35 ~ 18 48 W 1794:82 1706.00 1600.00 38 36 S 18 41 W 1027,Y9 1806 O0 1700,00 43 3? 2071,50 1906 O0 1800,00 47 51. ] ~21,7! 2006 O0 1000,00 48 1~ ]71,96 ~106 O0 2000,00 47 55 K20,59 ?206 O0 2100,00 47 56 660,38 ~306 ()0 2~00,00 47 30 2~16,~5 2406 00 2300,00 46 55 2069.53 2506 O0 2400,00 40 48 310B,45 ~606 O0 2500 O0 d6 ]K 3253.74 2706:00 ,2600:00 46 la 3397 59 2806,00 2700.00 45 30 353g 03 ~906,00 2ROO,O0 d5 5 3680 R8 3006 O0 2o00,00 44 39 3821 74 3106~00 3000"00 44 47 396P 35 ]206100 3t00,00 44 40 4103 27 3306,00 3200,00 45 6 4~45 .0 3406 O0 3300.00 45 41 4390:~6 3506:00 3400,00 46 50 453~,~6 3600 00 3500,00 47 49 4687.~0 3706:00 3600,00 47 37 n.Ot) 0,00 0.00 N 0.00 n.O0 0,01 ~,00 N 0,00 -n,?l 0.10 0,20 N 0.07 -0,53 0,24 0,52 ~ 0,13 -O,~3 0,()n 0,71 ~l 0,05 -O.64 0,lO (3,77 N 0,17 -n.83 o,12 0,90 ~ 0.20 -1.o6 0,86 1,24 ~ 0,20 -0,05 1.04 0,25 N 0,45 3,33 5,0~ .:{,Og 1],74 2,77 1.{,08 31.35 4,05 29,'/1 56,1.8 ~,OR 53,37 8R,04 3,44 84,5~ !27.14 2,70 122.46 174 35 3,47 167,91 230[06 4,04 29t,25 ~9~.04 2.16 284,62 ]71.87 3,30 355.78 S 18 16 W 45R.~ S 17 55 W 561.79 $ 17 39 W 673,36 S 1,7 1~ W 783.99 17 41] W R94 31 !.7 5~ w 1004:00 17 4~ w 11.11.~1 17 41 w 1,217.33 17 20 W 1323.O7 ~7 2B W ],427,93 $ t7 26 W 1530,g0 $ 17 31 W t631,57 S 17 35 W ],730,40 S ~7 43 W 1~20,!4 S 17 45 W lq27,51 S ~8 46 W 2026,37 ~ 22 6 W 2~27.~1 $ 25 34 W 223~,03 S 76 0 W 2341,~1 S ~5 49 W 24~{,77 1,27 W 3,.33 $ 27 78 4,36 W 13,"19 S 1{~ 24 W 10.27 W 31 '.~,3 ~; lc) 4 W 18,10 w 56 36 8 18 44 W 20,30 '4 R8 52 S 17 tO W 37,05 W ~27 95 8 16 50 W 50,89 W ~75 45 S 16 51 67 ,89 W 231,43 5 17 3 W ~9,7R W 208,45 8 17 ']0 W 1~3,99 W 373,60 8 17 45 ~'~ 3. '77 !,36 0 27 0 !8 0 39 0 4~ 0 3o. 0,30 0,32 0,34 438 11 S 141 52 w 460,40 6 1.7 54 w 53o 86 S 173 67 W 564.25 6 17 55 W 643 58 S 207 94 w 676,34 $ 17 54 W 749 64 S 231 ~3 W 787,53 S 17 50 W 855 48 $ 274 48 W 898,43 $ 17 4.7 ~ 96~) 33 S 309 37 W 1008,01 $'~7 47( 1063 25 $ 3.41,41 W 11!6,72 $ 17 48 lI64:43 S 373,71 W ~222,93 $ 17 47 a~ 1265,73 S 405,83 W !379,20 S 17 46 W 1,365,26 S 4]7,47 W 143~,59 6 17 ~5 ~ 0,44 0,31. 0 27 0 27 0 2] 2 39 1 48 ! 54 0 14 0 1~ 9q S 17 44 W 1464.89 $ 468,5~ W 1.537, 15~1 50 S 408,94 w 1639,28 $ 17 43 w 1,656 20 S 5~8,9~ W ~738 61. 6 17 42 W 558',96 83 5 17 42 W 589,07 !9]b 66 S 17 42 W ~9.5~ 1750 184.4 1939 ~034 21~9 727~ 232b 76 S w 1837 9O $ W 42 S W ?035 38 S 6~5,40 w 2137 56 S 607.96 W ~241 07 S 745,87 W 9349 94 S 793,94 W ;458 96 8 17 42 w S 1.7 51 ~' 65 S l~ 50 w APCO ~bASKA, TNC, KUP~RIIK N~R?H $~OP~ALASKA COMPUTATION DA f~.: 4-~,~A¥-85 DATC OF .~URV~:~: 30-.~,1AR-85 K~:LLY BUSH[N~ EGEVATION~ INTERPOI,ATED VAI,UFS FBi: CVEM 100 ri,3~'~'l' OF SUB-SEA I)EP'I'U lOo. O0 FT TPUF SUR-$E~ COUPSF MEA$11RFD VFRTICAb VERTIC~b DEVTATION AMIMIITH DEPTH DEPTH DEPTH DE~ MIN DFG MIN v~iPTTCAL DO,;LFG RFCTANGUbAR COL}t~[)TNATMS H[3RIZ, D~PAR'L~INE $~CTI.~N SEVERITY NORTH/~OUTH EAST/W~RT DIST. AZI~,~U'rN F~ET D~r~/1 oO FEET ~E~T FEET DE~ 'Ii~ 4835.47 3806.00 3700,00 47 34 4983.~2 3906,00 3RO0.O0 47 26 5t31.~0 4006,00 3~00,00 47 15 5277.~8 4106,00 4000,00 46 49 542],56 4206,00 4100,00 46 25 5568,39 4306.00 4~00,00 46 36 5714.~6 4406,00 4300,00 47 23 5R6~.03 ~506.00 4400,00 47 4~ 6011,50 4606 00 4500.00 ~7 2~ 6~.57.~ 4706:00 4600.00 46 ~ P5 34 W 256n.&4 ~ 25 23 W 2669.73 S 95 2] W 277~.33 $ 25 3~ w 2885,71 S 75 3~ W 2o91.42 S 26 29 W 3096.~7 $ 27 5~ w 3~02.79 K 27 43 W 3~1~.~9 $ 77 4 W 342~,23 ~ ~6 5~ W 3526,85 6~0~.53 4806 O0 4700.00 05 39 644~.K8 4906 O0 4RO0.O0 45 36 6586,00 5006 O0 4~00,00 45 58 6733.91 5106 O0 5000 O0 47 22 6884,,7 ,206 O0 5100:00 49 4" 703~.06 ,30'6.00 5200.00 ~9 51 719~ 56 540~00 5300,00 48 4~ 7343:~8 550 O0 5400,00 47 2~ 7489,58 5606,00 5500,00 46 7633.08 5706,00 5~00,00 45 29 $ 26 50 W 373~.54 S 77 1~ W 394~.55 S ?6 19 W 405~.57 S 2b 43 W ~172,68 S 26 5 W 4280,07 $ ~5 q W 440~.72 S 24 32 w $ 24 25 W 461o,04 7775 72 5806 On 5700 o0 45 5,'1 7~20".66 5906 O0 5RO0:O0 47 10 806~.79 6006 00 5900 00 47 5] 891g 99 6106 on 6000:00 48 6 8286:00 6150 74 6044,74. 48 6 S ?5 39 W 471.~,68 S ?b 5~ W ,;816,49 g 27 q W 4026,3o S 27 1~ W 5037,43 S 77 18 W 5087.19 0,15 O,lg 0,40 0,25 1,94 0 27 1:07 0,33 2~25.55 $ B-~1,46 w 2567,37 $ 1 2574.12 S 8R~.Jq W Pb75,90 S 19 27~9,31 $ 9~1.18 W ~890,91 S lq 50 w 2814,74 S 102b 86 W 2996 20 S 20 2909,05 S 107~47 W ~100 44 3003,90 S 11~20~ W 3206 3100,97 S 1173,58 W 3315 57 S 20 3198,07 S 12P3,44 W 34~4 3292,37 S 1271.50 W 3529.37 0,29 0,1P 1,84 0,6~ 1,44 0,43 0,81 1,66 0,68 1,36 3J84,07 S 1317,94 W 3631 3475,35 S ~364,13 W 3733 3566,35 K 1410,1~ W 3835 3~62,04 ~ 1459,0~ W 3942 3763.31 S 1509.65 W 4054 3869,83 5 ~563,&4 W 4173 3974,2% S !6!5.34 %~ ~289 4075,46 S 1663,78 W 44~1 417.'L,57 S ~708.36 W 4507 4265,37 S 1750,73 W 4610 0,70 1,20 6,40 0,00 0,00 4357,36 $ !70~,11. W 4712,26 4451,77 5 1.839,88 W 4816,90 4550.48 ,q ~88~,31 W 4926,"/~ 4649,46 S 1939,42 W 50,~7,74 4693,79 S1962'3J W 508'1,47 ARCO AL,~,.SKA~ TNC. 2U-6 K~IPARI~K NORTtt ,SLDPE ~ AI~. A,qK A ~ARKER TOP UPPER B~SF UPPER TOP b~WER BASE LOWER TD SAND RAND SAND SAND CO~lPU?ATION DA :(F.: 4-~u AY-R.5 INTERPOLATED VALUFi$ FflR CHUSE~! H[]RIZON.5 MEASURED ~RTGIN= 546' TVD SUR-SEA 7'/01.0n 575].78 5647,7~ 7754,0~ 5790.R7 5684,87 7830.00 5843.67 5737.67 RO!O,OO 5066,24 5860,24 12 UO 6047.e2 5941,97 .2~6:0n 6150.74 6044,74 PAG~ 7 DATE UF SURVF¥: 30-M~R-65 KELLY gUSHTNG EbF. Vt~TIUN: E~GTN~iER: LF, Sq I ~ 4t09,17 $ 1771.01 4343,32 $ 1787 37 439~,57 $ 4511.1.0 S 186~ 4591.q3 S 1909,7(.) 4693.79 S 196~,3! A~CO AI, ASKA, KUP~RIIK NIqR?H St,OPE,ALASKA DATE OF SURVFX: 30-~'4AR-85 KELLY P. LISHINC., FTLFVATTDN: MARKER MEASUP~ TVD FSL,718' SURFACE LOCATION AT F~,~,SEC 32,T12N,Rg~,I).~,, REC ANGI)GAR COORO)~IES N(JRTH/SO~TH CAST/WES% TOP UPPER SAND BASF UPPER SAh~D TOP bnWFR SAND BASE LOWE~ RAND TD 7701,0~ 575t.78 5647.78 7754,00 5790.87 5684,87 RB30 O~ 5~43.67 ~737,b7 . OlO:Ofl 5~66.24 5860,24 132,0n 6047.02 5941,92 . 2~6,00 6150.7'% 6044,74 430Q.17 $ 1771 O1 , 4343,32 S t787~7 ~ 4197.57 S 1011. ~( 4511,10 S 186~. . 459!.03 $ 1g09.7() ..~ 4693.79 S lq6~,.31 W FINAL WE[,b bOCAT?OM AT TO: TRUE SUB-SE5 NEAStI~ED VERTICAL VERTICAL DEPTN DEPTH DEPTH D I ST.~,',4 CE AZIMUTH FEET OEG ~,ITN 8280.00 ~150.74 6044.74 50~7.47 5 22 4!, W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2U-6 F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 30 MAR 8S REFERENCE 000070341 SURFi~CE LOCATION 546' FSL, 718~ FWL S32, T12N, VERTICAL PROJECTION PROJECTION ON VERTICAL PLANE 2OB. - 2B. SCi:LEO IN VERTICAL DEPTHS HORIZ SCALE = 1/I000 IN/FT W~LL ~P~: zu-o SURFACE LOCATION' $46' FSL, 718t FWL, $32, T12N, ~'~RIzoNTAL PROJECTION NOR'rH 2000 1O13O -2OOO -~000 -4000 -SO00 SOUTH -6000 -4000 WEST SCRLE = 1/1000 IN/FT -3000 -2000 -1000 0 1000 2000 3000 4000 Suggested form to be inserted~in each "Active" well folder to check for timely compliance with our regulations. -OPerATOR, WELL ~AM~ AND NUMBER' Reports and Materials to be received by: ~--/~--~~ Date Required Date Received ,, , Completion Report Registered Survey Plat Inclination Survey Directional ~ - ~ ... .... , ~/' ~j' Dr~ ~te~ ~e~'t-~epo=ts ,,, Digitized Data , , ARCO Alaska, Inc. Post Office Bo~-..m~'360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the March monthly reports for the following wells' 1Q-3 2U-6 3B-13 17-11 1Q-4 2U-7 3B-14 L1-9 1Q-5 2U-8 3B-15 L2-28 2C-9 2V-9 3-16(W/0) L2-30 2U-5 2W-4 9-27 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/LI06 Enclosures RECEIVED APR 1 6 Alaaka Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO,._MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ × Workover operation [] 2. Name of operator ARCO Alaska3. Inc. 3. Address P. 0. Box 100360, Anchorage3. AK 99510 4. Location of Well at surface 546' FSL, 718' FWL, Sec.32, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' RKB I ADL 25644 7. Permit No. 85-19 8. APl Number 50-- 029-21282 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2U-6 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of Ha rch ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0115 hrs, 03/07/85· Drld 12-1/4" hole to 3656'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8286'TD as of 03/12/85. Ran OH logs. Ran, cmtd, & tstd 7" csg. PBTD = 8132'. ND BOP. NU tree. Secured well & RR ~ 0945 hfs, 3/14/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 105' Cmtd w/215 sx CS II 9-5/8", 36.0#/ft, J-55, BTC csg w/FS ~ 3642'. Cmtd w/730 sx PF "E" & 880 sx PF "C" 7" 26 0#, J-55, BTC csg w/FS ~ 8214' Cmtd w/375 sx Class "G" cmt + 250 sx PF "C" 3. · · · 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/OR/SP f/8268' - 3642 CNL/LDT/Nicro]og f/8268' - 7500' Cal f/8268 - 6500' 6. DST data, perforating data, shows of H2S, miscellaneous data NONE RECEIVED ^PR ! 6 Alaska Oil & Gas Cons, Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /i¢O~ ~JJ~ TITLE Associate Engineer DATE Z~-~-~ NOTE--Repor~ on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 .ll~lt4/HR7 ¢~ Submit in duplicate ARCO Alaska, Inc Pos! Office -ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ,', ,.'- ~". ,:: ..... ]: T H;" :'"' ~ ' "- ' ' ' - ~'-' ' ' ....[-0:-,,~ ~'J-"-.?ii::. ¢-.'7. :"*-i:?'- '""-'l": ~,.'"'"'; 'l .... I -~._£- F: r."-, ,",,.' i'",! E "' "g,." - F'Y .... IU:-,..I,~ 0 ,.:, .:. .,. r-,~ l:. i'; p.,...: OF T'."!Z2 .T,'""'"2?'i'rTTAL: - '-~ - CF'TJ?~.H,'".:L.': LIS TAPES '"'C>!' ~ ~ >,f '..".: = ':.: ;'; =' ,':,, (0,'~='' .TAPE F',_U., .o February 19, 1985 Mr. J. B. Kew in Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2U-6 ARCO Alaska, Inc. Permit No. 85-19 Sur. Loc. 546'FSL, 718'FI~U~, Sec. 32, Tt2N, R9E, UM. Btmho!e Loc. !067'FSL, !330'FEL, Sec. 6, TllN, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereUnder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing oPerations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. KeW~n Kuparuk River Unit 2U-6 -2- February 19, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~q~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this _ ~ ~ ~ have o~fice adequate advance notification so ~ha~ we may a witness present. Very_.truly yours, C. V. Chattertbn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conser~ation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B~,..~{00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 31, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2U-6 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2U-6, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on March 11, 1985. If you have any questions, please call me at 263-4970. Sincerely, ~re~'Dr~ ling Engineer JBK/HRE/tw PD/L29 Attachments RECEIVED F E B 0 5 1985 Alasi<a 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OTL AND GAS CONSERVATION C~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~(X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE E~X 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 j~ ~..~., ~._ 4. Locationofwellatsurface i~' L-L ~1 VED 546' FSL, 718, FWL, Sec.32, T12N, RgE, UM A ttopofproposedproducinginterval ~EB 0 ~ J985 1437' FSL, 1170' FEL, Sec. 6, T11N, RgE, UM Alaska Oil & (?as COns, At total depth 1067' FSL, 1330' FEL, Sec. 6, T11N, R9E, UM _ Anchor_%~e COmrnissi( 5.-~evation in f-----~et-(i--~di~ate KB, DF etc.) I 6. Lease designation and serial n~. RKB 106', PAD 69' I ADL 25644 ALK 2575 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 9. Unit or lease name Kuparuk River Unit 10. Well number 2U-6 30 mi. NW of Deadhorse miles 16. Proposed depth(MD & TVD) 8353' MD, 6163' TVD 11. Field and pool I? Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 14. Distance to nearest property or lease line ~ance to nearest drilling or completed 546' @ surface feet (x~_~w~ll 60' @ surface feet 17. Number of acres in lease I 18. Approximate spud date 2560 I 03/11/85 fe~t 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2688 psig@ _ROOF Surface KICK OFF POINT 600 feet. MAXIMUM HOLE ANGLE 48 Ol(see2OAAC25.035(c) (2) 3088 ..psig@ 6028 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD SIZE · Hole Casing CASING AND LINER Weight Grade i24" 16" 62.5# H-40 ~ HF-ERW 18-1/2" 7" 26.0# J-55 HF-ERW 22. Describeproposed program: Coupling/ Length 80' 35' I 35' I 3601' 8319' 35' 35' I 34' I I 34' MD BOTTOM TVD 115' I 115' 3636' I 2986' I 8353' I 6163' I I (include stage data) ± 200 cf Poleset 730 sx Permafrost "E" 880 sx Permafrost "C" 260 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8353'MD (6163'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3636'MD (2986'TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig~(3000 i~si for annular). Expected maximum surface pressure is 2688 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 2-7/8", 6.5#, J-55, EUE 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space belo Samples required l[]¥ES Permit number APPROVED BY Form 10~401 CONDITIONS OF APPROVAL Mud[]YEslog required~No I ~YESDirecti°nal[]NoSurvey required I ~7..~ ] Approval date L (HRE) PD/PD29 DATE IAPl number 50--o t9 -% SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE February 19, 1985 by order of the Commission Submit in triplicate :? PERMIT TO DRILL 2U-6 installed and tested upon completion of the job. 2U-6 will be the tenth well drilled on the pad. It is m 60' away from 2U-$ at surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6808'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the completion rig has moved off location, the well will be fracture stimulated. . . , , .~ ' [ - - ~. - ~ ~ ....... ~ ' " ~ ~ ~ ' i ~ ~ ~-[ ' , , ,,i , , .... ,. ~ . _~, , ~.~. J Alas~.~ Oit & Gas Cons. Surface Diverter System I. 16" - 2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling, spool w/lO" side outl ets. · 5. tO" ball valves, hydraulically actuated, w/lO" lines to rese~/e pit. Valves to open auto~t'ically upon closure of annular preventer. 6. 20" 2000 psi annular'preventer. 7. 20" bell nipple. · . Maintenance & Operation Upon initial insl~llation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines 'every 12 hours. Close annular preventer in the event~ that gas or fluid flow to surface is detected. If necessary, ~mnually ove~ide and close ball valve to upwind divertar line. Do not shut in well under any ci~umstances. , 16" Conductor RECEIVED AlasKa Oii& Gas Cons, commission Anchorage 7 6 L 2 4. ~~ ~ TO ~ ~I ~ ~ ~ ~0 ~ I~ 5. ~N ~ ~~ ~ ~ KI~ ~ ~ ~I. RECEIVED FEB 0 5 1985 nil ,~ ~n.~ rmn~. Commission Anchorage ARCO Alaska, Inc. ,...~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 25, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Conductor As-Built Location Wells 1-8, 9-16 Dear Elaine: Enclosed is an as-built location plat for you have any questions, please call me at Sincerely, J. Gruber Associate Engineer JG/tw GRU3/L77 Encl osure Plats - 2U Pad the subject wells. If 263-4944. ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany i W£LL 1 Y = 5,975,841.16 LAT. 70o20'42.7599'' X = 509,642.25 LONG. 149°55'18.2508,' PAD --LEV, 68.4 0,G, ELEV. 64.% FSL 575 FWL 1,096 i WELL 2 Y = 5,975,782.54 LAT. 70°20'42.1835'' X = 509,627.77 LONG. 149°55'18.6762'' · , PAD ELEV. 68.4 O.G. ELEV. 64.1 i FSL 517 FWL 1,081 WELL 3 Y = 5,975,724.43 LAT. 70o20'41.6122'' X : 509,613.34 LONG. 149°55' 19.0999" PAD .=LEV. 68.3 O.G. ELEV. 64.0 FSL 458 FWL 1,066 W.=LL ~ Y = 5,975,666.21 LAT. 70°20'41.0397'' X = 509,599.09 LONG. !49o55' !9. 5187" PAD ELEV. 68.4 O.G. ELEV. 63.9 FSL 400 FWL 1,052 WELL 5 Y = 5,975,753.43 LA'F. 70°20' 41.902" X = 509,249.86 LONG. 149°55' 29. 720" PAD .=LEV. 68.6 O.G. ELEV. 64.4 FSL 488 FWL 703 WELL 6 Y = 5,975,811.41 LAT. 70°20' 42.472" · ! X = 509,264.30 LONG. 149055' 29.296" · ~ PAD ELEV. 68.6 O.G. ELEV. 64.4 · 3 FSL 546 FWL 718 WELL ? Y = 5,975,869.59 LAT. 70020, 43.044" X --- 509,278.75 LONG. 1~9°55' 28.871" PAD ELEV. 68.6 O.G. ELEV. 64. FSL 604 FWL 732 WELL 8 Y = 5,975,927.80 LAT. 70°20' 43.616" X = 509,293.26 LONG. !-~°55' 2~.445 31 32 FAD ELEV. 68.5 O.G. ELEV. 64.2 FSL 662 FWL 747 6 5 OF TOWNSHIP 12 N, RANGE 9 E, UMIAT MER. NOTE' BASIS OF BEARING IS PAD PILING CONTROL N 13+55. E8+30 AND N 13+55, E 11+70 AND ~,~.~,, ~-.,..;,.~_~: ..-..,,, o,,,~ BASIS OF ELEVATION IS 2U-5 AND 2U-4 PER ~., £$$10~t. ~.? LHD E~ ASSOCIATES. ' ~ - I HEREBY CERTIFY THA~::'I AM PROPERLY REGISTERED AND . , LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS -? .,.,.~ ~.-...-. ARE CORRECT AS OF · ARCO Alaska, Inc. DRILL SITE 2U IIIII oo ,o,s ,k.-u~, ~ / ~,..~SCALE: I"= I Mile'~-' Drawn By' HZ Dwg. No. NSK9.05.221d I CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (~2 thru' (3) Admin (~ ( 9 / t h r u 1~2 )o~// '(10' and '12)/ '(13 thru 21) (22 thru/ 26) 1. Is the permit fee attached .............................. 2. Is well to be located in a defined pool ................. 3. Is well located proper distance from property line ...... 4. Is well located proper distance from other wells ........ 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included .... 7. Is operator the only affected party ..................... 8. Can permit be approved before ten-day wait .............. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO e . o e · · · e · · e~ · o . · o · REMARKS Does operator have a bond in force '... ................................ Is a conservation order needed ...................................... ~/~ Is administrative approval needed ........ Is the lease number appropriate ...... Is conductor string provided ............................. Is enoUgh cement used to circulate ~'con~tor an~'Surf~ce' .: .... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ........ i ........... '~ Will surface casing protect fresh water zones .......... '~" ~ Will all casing give adequate safety in collapse, tension and burst.· Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ .~/~ .. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached .... ~' .i Does BOPE have sufficient pressure rating - Test to' ~D psig Does ~he choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks o H 0 Geology: ~ Engineering: rev: 10/29/84 6. CKLT POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. o ON/OFF SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi ., No special 'effort has been made to chronologically organize this category of information. 5VP OIO,H02 VERIFICATiOi~ LISTING PAGE 1 ~* REEL HEADFR ~ERVICE NAME :EDIT 9ATE :~.5/03/77 3RTGIN : CBNTINI~A~ION ~ :01 PREVIOUS R~EL ,,CO~MENT6 ~ TAPE HEADER ~ERVICE NA~E :EDIT DATE :R5/0]/97 9RIGIN :0000 TAPE NAME :Olql CONTINUATION ~ PREVIUUS TAPE : COMMENTS ** FIbE HEAOE~ ** FILE NA~E :EDIT .001 SERVICE NAME : VERSION# ~ DATE : ~AXIMU~ LENGTH ; 1024 BILE TYPE : PREVIOUS F~LE : ** INFORMATION RECORDS ** MN~M CONTENTS CN : ~RCO ALASKA WN : 2U-6 ~N ~ KUPA, ROK RANG~ gE TOWN~ 12N SECT~ 32 COUN~ ST~T: ALASKA CTR¥~ USA ~NE~ CONTENTS ** COMMENTS ** UNIT TYPE CATE SIZE CODE 000 000 01,5 065 .000 000 004 065 000 000 007 065 000 000 002 065 000 000 003 065 000 000 002 065 000 000 007 065 000 000 006 06 000 000 003 065 000 000 001 065 ~VP 010,NOP~ VERIFICATION bI6T1NG PAGE 2 ~ $CHLUMBF, RGER ~ ALA~SKA COMPUTING CMi~TE~ ************************************************************************************ ~[3MPANY = ATLANTIC ~ICHFIEbD CO~qPA{'~Y 4ELL = 2U-6 ~IELD = KUP~RUK ~TAT~ = At, ASKA .lOB NUMBER AT ACC: 70101 RUN #ONE, DATE bOGGED: 5DP: ~ASING : 9,625" ~ 36,00' - BlT SiZE : 8,5" TO X' ~YPE FT.UTI) = POLYMER DENSITY : 11,1. LB/G RM = 3 320 @ 66,0 D~' VISCOSITY : 4~,0 S RMF : 3:090 @ 66,0 DF PH = 9,5 RMC : 3,090 ~ 66,0 DF PI~I.JID [~OSS : 4,0 C3 RM AT BHT - 1,605 8 144,0 DF MATRIX SANDSTONE ******************************************************************************** JVP OIO.HOP_ VE~IF1CATiOi'J LISTING PAGE 3 $ , * · , $ * , , , ~ $ · , , , $ * , , , , * , , , , , · $CHbI}MBE~GKR LOGS INCLUDED WIIM THIS MAGNETIC TAPE% , · DUAL [~tDIICTION SPHERICALLY E'OCUSFD bOG (DIL) · MICROLATERLOG (MLL) · LITttO DEM$ITY COMPENSATED LOG (LDT) , , , * , ~ · , , , * $ , * , , * , · , * , $ * , , , · , ENTRY BLOCKS 2 ! b6 0 4 1 66 8 4 73 60 9 4 65 .lI~ ~6 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS ~NEN S~RVlCE SERVICE UNTT APl[ API APl API FILE SIZE *PL. REPR ID O~DER # bOG TYPE CLA6S ~OD NO. DEPT FT O0 000 O0 0 0 4 SF[,U DIL OHMM O0 220 Ol 0 0 4 ILD DIL OH~ O0 1.20 46 0 0 4 IL~ DIL OH~ O0 120 44 0 0 4 SP OiL MV O0 010 Ol 0 0 4 GR DIL GAPI O0 i)10 O1 0 0 4 GR I,[)T ~API O0 310 Ol 0 0 4 CALl ~,DT 'IN O0 280 O1 0 0 4 RHOB LDT G/C3 O0 350 02 0 0 4 DRHO LOT G/C3 O0 356 Ol 0 0 4 gHAT LDT O0 420 Ol 0 0 4 PROCESS CODE ¢OC1Ab) ! 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1. 68 00000000000000 i 68 00000000000000 I 68 00000000000000 ,1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 VERiFICATiON LISTING PAGE 4 RHOB ,~PHI 0EPT Np~I OEPT SP GR SP GR SP ~PHI 8307 0000 -66 5000 14 1484 37 0605 -099 25O0 8300 0000 -65 5000 14 !,484 41 6992 -999 2500 O0 000 O0 u PU O0 ~90 O0 0 nO 358 O1 0 CPS O0 330 31 0 CPS O0 330 30 0 GAPI nO 310 O1 0 TN O0 280 O1 0 OHm~ O0 252 O0 U OHmM O0 250 O0 O 8200 0000 -2~ 4063 '. 4492 39 4531 107 3750 8100 0000 -37 4375 2 3438 46 ~891 98 875 8000 0000 -37 5000 2 3477 29 0527 75 56~5 SF[,U ~R DRMO SFLU DRHO HD SFLU DRUO PEF H O GR DR~0 PEF HD SFLU DR~O PEF gD DEPT 7900,0000 SFI,,O SP '59,9375 GR RHOE~ 2.2754 DRHO gPHI 27,0996 .PEF GR 78.2500 HO 7800 0000 -67 3750 2 ~512 27 832 86 0625 OEPT SP RHOB S F L U GR DRHO PEF ~D -101 -101 10 3 6992 o: 5ooo 3 4785 5~0547 7.5522 3,6992 0,5000 3.4785 6.08~0 7.55~2 3.3809 7.3750 O,OI4U 3.0723 9,2656 3 7441 98 6875 0 0137 4 3203 9 6763 1~ 2500 7 5625 -0 0054 2 9297 9 1763 2O .1250 78 2500 0 .0073 2:7266 9 0591 7,0156 86.06~5 0,0137 3,3633 9.5669 GR NRA~ NCNL ~NOR NRAT ~C~b ~NDR ~NOR GR ~RAT NCNL mNOR GR NRAT NCNb ~NOR NRAT ~NOR ~R 0 4 0 4 0 4 0 ~ 0 4 0 4 0 4 0 ~ 0 a 6.4414 '1010.5000 3.1641 '21040 0000 '9991~500 3,2344 -1010.5000 3,1641 -21040,0000 '999,2500 3 3 2084 2 0625 3750 3633 0000 5566 3,~207 98,6875 3,7656 1857,0000 2,5605 7,1562 75,5625 ~,7246 2560,0000 7.0391 1,5.6172 78.2500 2.5762 2698.0000 9,4740 86, 25 2,6738 2606,0000 4,6875, 1 68 I 68 1 68 1 1 1 1 1 CALl RNRA FCNL CALI RNRA MINV' CALl FCN~ MINV CALl RNRA FCN5 MiNV CALI RNRA FCNL MINV CALi RNRA FCNb MI~V CA,LI RNRA FCNb ~iNV 00000000000000 00000000000000 00000000000000 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 3,4512 8,5000 3,3281 320,0000 ~999,2500 3,4512 4 5078 3,3281 -6320.0000 -999,2500 3 0488 9 ]359 3 785 599 0000 2 7090 3,2813 9,6641 3,7285 498,0000 2,8932 7,4375 703 9'0613 6 211 1~,41'41 8072 2'64.~6 o2 :sooo · 730~ ~,.7070 ,4922 ~,~72.27' 9'57~0000 5,9049 '-,VP 01o,~.~02 VEPIFICATiON LISTING PAGE 5 }EPT ~PHI ~R ~EPT SP DEPT SP RHOB DEPT SP MPHI OEPT SP RHOB ~PH1 DEPT SP RHOB ~R ~P ~PHI ~R SP NPHI NPHI 7700 0000 -70 4375 2 5879 31 3477 112 4375 7600 0000 -78 1250 P 4043 41 6504 ~23 7500 SFLb ~R DRHO PEF ND SF[.U DRHO PEF ND 7~00,0000 SFLU 90,1~75 GR 2.3574 DRHO 39 ill3 PEF 135:~750 WD 7400 0000 -96 1250 -999 2500 -999 2500 -~99 2500 7300 0000 -95 8125 -999 ~500 -~99 2500 -999 2500 SFLO DRHO PE;F H D SFLU D R H 0 PEK 200. 0000 SFI,U 1,13.0000 GR 7 1 O0 0000 . -107,7500 Ga -990,~500 DR~tO -990.~500 PEF -999.2500 7000 O000 SFLU -999, P500 -~99, P500 6900.0000 SFLU -J. 50.,~250 GR -99q,~500 DRWO -999 2500 PEF -099: 2500 2 0586 0.0146 5.5625 10.0674 2 5801 123:7500 0,0244 3.2637 ~,6270 3 0234 135 8750 0 O083 3 0625 10 5430 3 8047 lU5 1250 -999 2500 -~99 2500 9 8848 NRIT UNOR GR ~NOR NRAT NCNL ~NOR GR NRAT 4.3828 233.7500 GR -999,2500 NRA,T -99~,~00 NCNL 9. ~9 MNOR 6.1641 1.1~,5~25 6R '999.2500 N'RAT '999,~500 ~CNL -999,2500 ~NOR 3,7676 123,9375 -999.P500 NR~ -090,2500 -999,~5~0 9.3047 ltd 83,7500 GR -099,2500 ~R~T -999.,2500 ~CNb -q99,9500 ~NOR 5,0039 ILD lO1 75OO nR -999 ~500 WRiT -099 2500 WCNL -099 2500 ~NOR 3.3574 112,4375 2,9551 2880,0000 ?.0947 2 4160 123:7500 3.6211 1748,0000 2,1823 2.8672 135,8750 3.4609 1873,0000 2.0299 3.2988 1.85.1250 '999.2500 '099.2500 '999.2500 3,0469 233,7500 -999,2500 -999.2500 -999.2500 4,5781 112.5625 -999,2500 -999.2500 -999,2500 3,1.914 123,9375 -~99,2500 -990,~500 -099,~500 6,9648 83,7500 -999 ?500 -999'2500 . -999.2500 4.8633 1,01,7500 -090,~500 '999,2500 CA[, I RNRA FCNL MiNV CALl RNRA FCNL CALl RNRA FCNb ~INV CALl IRNRA FCNL CALl RNRA CALl RNRA FCNb 'M1NV CALl RNRA FCNb ~INV CALl RNRA FCNb ~INV CAI, I RNRA FCNL 3 1406 10 03!3 3 1113 925 5000 2 2982 2 4336 ~,1680 419.2500 2,4160 2 7539 10 8203 3 7598 498 0000 2 3470 3 3711 9 9766 -999 2500 -999 2500 -999 2500 3 1641 9 6484 -999 2500 -999 2500 -999 2500 :5352 8125 -9~9,2500 -999,2500 -999,.2500 3.1.797 10'0859' -999,~.500 -999,2500 -999,2500 7 4 88 3 9 6172 -999 _2500 '999 2500 -999 2500 4.9062 9,9375 '999,2500 '999,~00 -999, O0 5VP OlO.P02 VE~IFICATIO~ LTSTING PAGE 6 5¢ -134.6250 ~R RHOB -099.75~U DRNO qPHI -~90,~500 PE~ ~R -99Q.~500 MD DEPT 6500,0000 sP -12o RHOB ,090: 2500 ~]~wI, -099 ~5o0 GR -q9q: PSO0 EPT 640n,0000 SFLU SP -124.5625 GR RHOB -999 ~500 ~R -999,~500 HD DEPT 6300,0000 SFLL) SP -~_41.7500 GR RHOB -090'2500 DRWO NPHI -990.~500 PEF ~R -099.~500 [~D DEPT 6~00.0000 S~L.I"' l SP... :130.~7S0 ~ ~HOB 090.7500 ~RHO NPHI 090 ~500 PE~ OEPT 6).00,.0000 SF[,O 8P -127'312b GR RHOB -090,2500 DR,+~© MPHI -990.~500 PEF GR -09O,2500 ~ID 107 -09o -~99 -99o -09o -099 -ggO 3 126 -999 -090 3 98 -990 -990 -999 4 -999 -099 -990 3 -999 -099 -999 173 -099 -g9g -999 )50 -090 -990 I 45 -og9 -090 -990 .!6~0 .06~5 .~500 .~500 .25n0 .4941 .~750 .7500 .2500 .2500 .65~4 .0695 .2500 :~500 2500 .1719 1875 :9500 .2500 ,~500 75)9 .2500 .~500 .PSO0 .6348 2500 :P500 .2500 .~500 .5547 .nOOO ~500 :2500 ,2500 .0752 .0000 .2500 .P500 .2500 .281,3 .2500 ,~500 .2500 .~500 ILD NCNL GR NR~T u C N L ~N{3. R I OR NRhT NCNb ~NOR Ibm NR~T MNOR ~R NR~,T N C N L, NR~T ~CNL MNOR N R A T NCNL UNOR I L O N R h T MCNb MN'OR 107. -999. -090. -990, -099. -999. 126. -099, -999, -999, 9~. -099. -999, -099. 4 -099: -qgo,. -999, -999. -999 ,, -999, -999 -099: -999. -999. -999, -999, -999. J -990. -999. -999. -990. 9258 0625 2500 ?50O 7500 1016 n750 ?500 2500 2500 5566 0625 2500 2500 2500 7910 1875 2500 25OO 2500 1406 2500 2500 2500 2500 8398 2500 2500 2500 2500 654.3 ~500 ?500 2500 2500 2 ~7 2150o 2500 ?500 2500 2344 2500 2500 2500 2500 CALi RNRA FCNL CALl PNRA ~INV ILM CALl ~NRA FCNL MINV CAI.,I P~NRA MINV IbM CALl RNRA FCNB MINV CALl RNRA CAt, I RNRA MINV C A L I FCNL MINV IbM CALl RNRA FCNb ~INV 4.0000 9.9844 ~o99 9500 q9o'2500 . -999,2500 3.0723 9 6797 -999:2500 -999,2500 -999,2500 3 5469 10:390b -099.2500 -999.2500 -099.2500 3.7539 q 6406 -99f}i25oo .999 2500 .999,25oo 4,168o '990.25oo -999,25oo -999'25oo -999.25oo 3,7461 :999 2500 999: 2500 ,.999 2500 -09922500 2,~762 -990. 500 -999.2500 -/~99'2500 -099,2 S 00 I 09 -999 ~500 -999 250{) -999 2500 4 1,21,1 -999 2500 -999 2500 -ogg 250O, 0 -999 25.0 5V~ nln."0? VEPlFICRTIO. N ][,~SmING PAGE 7 )EPT 5aOa..ri. OhO SF[,U 3P -_~ 39... 5000 ~R ~HOB -o99.P. 500 DR~O qPR1 -99a.2500 PEF .~R -999.9.500 ND 3EPT 58On.nO00 SFLU ~P -137.1250 gMnB -q90.~500 gPgi -099.2500 PEF ~R -990.P500 ND OZPT 5600.0000 '~HOB =09c~ ~500 gP~aI -~99~2500 PEF GR -990.2500 DEPT 5500.0000 SFLU SP -143.P500 GR RHOB -a9q.2500 DRHU gPHI -~99.~500 PEF GR -999.~500 ~D DEPT 5400.0000 SFLU SP. -145.3750 RH[)B -999.~500 DR~O NPHI -099,2500 PEF ~R -g9g. PSO0 DEPT 5~00 0000 SFI.,,U Sp -~48i3750 GR Rf:tOB -999 ~500 DR~O NPM'I -090 ~500 PEF GR -999.~500 ~O -999.2500 -099.~500 -990.2500 ~.g160 Tb9 97.B1~5 gR -~90.7500 NRhT -990.~500 MCMb -990.2500 ~NOR 2.7793 11~.7500 -090.2500 ~RAT -990,2500 -990.7500 MNOR 2.~730 ~LD 65.5625 GR -099.~500 NR~T -990.~500 NCML -990.7500 ~NOR 2 ~105 IbD 9~6250 GR -99a,250() ~IR~T -999. ~500 ,MCML J1!.,4375 GR -999.~500 NRAT -090.~500 ~C"b -~99,~500 MNOR ~.87~9 95.6250 -999,2500 MRIT -999.~500 -990.~500 MNOR ~.8770 IbP ~09,!875 GR -999.2500 NR~T -090.P500 NCNb -999,~500 MN~R 1.8709 -090.2500 -999.2500 -990.~5n0 -999.2500 3.0703 -090.2500 -999.2500 -999,2500 -a90.2500 2.7051 -999,~500 -090.2500 -999.2500 -990.~500 3.0684 -999.~500 -999.2500 -999,2500 -~99.2500 2.9805 -999.2500 -999.2500 -999.2500 -999.2500 2,8164 '999,2500 -099.2500 -099.2500 -990,~500 -999:~ 00 -099,2500 -099,2500 -~99,2500 2,~223 -999"2500 -999.2500 -990.2500 -999.2500 ~.80~7 -999,~500 -999.2500 -999,2500 CALl RNRA ~CNL MINd Ib~ CALl FCNI., MlWV Tb~ CALl RNRA FCML MiNV CALI RNRA FCNb ~INV I l, M CAbI RN;~A FCNb ~INV' CAbI RNPA FCMb MINV RNPA FC~t,L, RNRA ~INV IbM CALl RNRA 1.7920 -999.250o :ggs. soo 99,2500 -999'2500 3,3047 -099,2500 -099.2500 -099.2500 -999.2500 2 6875 -999.2500 -999.~500 -099.~5~0 -999,~500 ],0449 -999.2500 - 99 2500 - 99: soo . -999,2500 -999,~500 -999,~500 -~99.~500 -999,~500 2 422 -999 -999 2500 -999 2500 -999 2500 2 7508 -999 2500 -999 2500 -999 2500 -999 2500 2 8652 -999 ~500 -999 500 -999 2500 -999 ~500 2 6855 -o9g 2500 -999 o0 -999 2500 5VP OlP.WO? VEP[F'I:CA'r'InN LISTING PAGE 8 gEPT 4gOn. O000 SFLU SP -17o.3750 GR ~HnB -~90.2500 ~RNO NPgI -~9n.25nO PEP GR -~9~.7500 ~D DEPT _4.700 0000 SFLU GR -~90'~500 ND DEPT 4400.0000 SFLU Sp -186.5000 RHOB i990,2500 DRHO ~PHI 990.2500 PEF GR 990'2500 DEP~ 4300,0000 ~p. -~99.0000 R~OB -090,2500 DRHO gPHI -999,:2500 PEF GR -99~.~500 OEPT 4200 0000 ,SP -320,0000 ~HOB -090,~500 DRHO NPHI -999,2500 PEF ~R -099,2500 ND 2.6406 TbP 90.3125 OR -090.2500 ~IR~T '09~.2500 uCCeL -990.25n0 2.6504 TbD 112.3750 GR -099.2500 NRAT -999.2500 ~C~L -099.2500 UN~R 2.5137 113.7500 ~R -099.2500 NRAT -o99.2500 NCNb -09~.2500 3 5O00 ?LD ~23:4375 ~R -999.2500 WRAT -990.2500 ~CNL. -990.2500 MNOR 2.98~3 95.6250 nR -999,2500 NR[T -090,2500 NCNb -099.2500 UNOR 4.~367 Ibg 1,10,6250 OR -999.2500 NRAT -999,2500 NCNI~ -090,2500 ~NOR 3.4980 IhO 10'1.0625 OR -990.2500 WR~,,Y -999.2500 NCN[~ -990.2500 MNOR ~,7949 94.3750 -~og ~5oo -,.99:2500 NCN~ -~9~.2500 3 3203 IisD 1,07:0000 GR '999.2500 NRAT '999.2500 NCNL '999,2500 MNOR 2,P437 -990.2500 -090.2500 -099.2500 -99~.7500 ~.8887 -990.2500 -999.2500 -090,2500 2.84~8 -999.2500 -099.2500 -999.2500 -999,7500 3.7605 -990,2500 -999,2500 -999,2500 -999,2500 3.3672 -999.2500 -999.2500 -999,P500 -999.2500 4 32~2 999,2500 -999.~500 ~999,~500 3 6543 -999 2500 -999 2500 -999 2500 -999.2500 4 3242 -999:2500 -099.~500 -999'2500 -999,~500 3,7598 -099,~500 -099.~500 -999.2500 -999,~500 CALl RNRA FCNL ~INV CALl PNPA FCNL ~INV CALl RNRA FCNb ~IHV CALl RNRA FCNL ~INV CALl RNRA FCNL FC~!b Mi, NV IbM CAbl RNRA FCNb NINV IbM CALl RNRA FCNb MINV CAbI RNRA FCNb ~INV 2,7383 -099,2500 990,2500 :09~.2500 -999,~500 2.7207 :999.~500 999.2500 -099.2500 -099,2500 2 6855 -099!2500 .°99 ~500 -~90 ~500 -999 500 3,6484 -999 2500 '999i2500 -999 2500 -999 ~500 3 1484 -g~g 2500 -999 2.500 -099 2500 -099 2500 .4 0430 -999 2500 -999 2500 -999 ~500 -999 500 3,~922 -099, 500 -999,2500 -999,2500 -999.2500 4,1~33 -999.2 O0 -999 ~500 -999' , 500 '999,~500 3 5059 -999 2500 -999 2500 -999 2500 -999 2500 JVP 01~.~409. V~.~PIFICATION 5ISTiNG PAGE 9 ~EPT 4100.00n0 SFr. U ~P -328,~000 CR 96, ~HOB -~99,~500 DR~IO -q99, ~PMI '~9~ ~500 DEF ~R -999~500 ND 'egg, )EVT 4000.0000 SFLU 3. ~P -332.750o ~R 103. ~PH1 -a99.~500 PEW -ag~, ~R -o9~,~500 ND DEPT 390~,0000 SFLU Sp -~$q.5OnO GR RHO~ -~9~..2500 nRHO gPWI -~99.~500 PEF :R -999, ?..500 FI[) DEPT 3~O0.nO00 SFLU 5P -~65.5000 RHOB -09~,~500 DR~O ~P~I -099.~500 ~R -099"~500 DEPT 3700,0000 SFLU SP -250,0000 GR R, HnB -~9~ ~500 DRHO MP~I -09~i2500 PEF ~R -~99 ~500 t4[) DEPT ]634 0000 SFLU RHOB -~99,P500 DR. MO MP~I -099,~500 PEF ~R -.999,~500 Mil) ** FILM TRAILER ** FILE ~A×I~Li~ LE~GTH : NEXT FILE ~A~E : 3711 8125 2500 2500 7500 .00:1. EOF ** TAPM TRS,ILER ** MERV~C~ NAME DATE :~510~/27 ORIGIN :0000 70nO 8'150 ~500 2500 5.0352 ~04.3125 -~9~.~500 -999,2500 -999.2500 3 94~4 ~08~7500 -09~.~5~0 -~99,~500 -999,~500 4,6250 88.5625 '999,2500 '99~,~500 '99~,~500 3,3281 59,6875 -~90,~500 -~99,~500 -99~,~500 ~R NRhT NCNb UNOR ~R NRAT NCNb MN~R NRAT NCNb NR~T NCNb ~NOR ~R NRAT MNOR GR NRAT ~NOR 4,7930 -999,2500 -09~,2500 -99~,2500 -99n,2500 4.0580 -g9n.2500 -q99.~500 -999.2500 -ogm.25nO 5,2500 -990,~500 -999.2500 -999,2500 -999,~500 4.,2187 -999,~500 -999.~500 -999,2500 -~99,~500 -999,~500 -999,2500 -999,~500 1~.5859 -999,~500 .-999,2500 '99~,2500 -999,~500 CALl RNRA NCNb ~INV CALl RNRA FCk'b ~I NV CALl RNPA FCNL RNRA ~CNL ~INV CAbi ~NPA FC~b CAbI RNRA FCNb ~INV 4 5469 -~99:2500 -999,~500 -99~,2500 -999,2500 3.8359 :099,2500 999,~500 999,2500 4.6992 -999 2500 '099i2500 -999 2500 -999 2500 4,011.7 -999,2500 -999,2500 -,099 2500 999:2500 4 7266 -999 2500 -999 2500 -999 2500 -~99 '~500 2000,0000 -999" ~:500 -999,2500 ,2999. '2,.500 999,~500 PAPE N A ,~,~ ? :nlql
